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198-080
STATE OF ALASKA ALQA OIL AND GAS CONSERVATION COM•SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Plug Perforations LI Fracture Stimulate U Pull Tubing LJ Operations shutdown Lf Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: _Tubing Punch&Gas Lift_ Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: SAVANT ALASKA,LLC Development Q Exploratory ❑ 198-080 3.Address: 601 W 5TH AVE,SUITE 301,ANCHORAGE, Stratigraphic❑ Service ❑ 6.API Number: AK 99501 50-029-22880-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL 367006,ADL 367011,ADL 365533 B1-16 A iI 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N O V 3 0 2016 n/a Badami Unit/Badami Oil 11.Present Well Condition Summary: i*"lO3 C(�`,a„ Total Depth measured 13372 feet Plugs measured None feet true vertical 10633 feet Junk measured None feet Effective Depth measured 13286 feet Packer measured 11557 feet true vertical 10549 feet true vertical 8965 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 110' 110' 1530 psi 520 psi Surface 5342' 9 5/8" 5377' 4600' 6820 psi 4230 psi Intermediate 11895' 7" 11928' 9287' 9690 psi 9200 psi Production Liner 1620' 4 1/2" 13372' 10633' 8430 psi 7500 psi Perforation depth Measured depth 12770'-13190' feet SCOW MAR 13 L ui z?, True Vertical depth 10334'-10456' feet Tubing(size,grade,measured and true vertical depth) 2.875" L80 11423'MD 8794'TVD Packers and SSSV(type,measured and true vertical depth) HES 7"x4 1/2"TNT Packer 11557'MD 8965'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 41 0 0.595 390 144 Subsequent to operation: 226 n/a 0.382 1296 668 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory LII Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil U Gas U WDSPL 7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Conrad Perry Email cperry@glacieroil.com Printed Name Conrad Perry Title Drilling Manager Signature �i. / Phone 907-727-7404 Date ,/i /tJ Form 10-404 Revised 5/2015 G\E - /2-C --/4„,. Submit Original Only ff � / 6 RBDMS V/ Du - 6 2016 • RECEIVED GLACIER NOV 3 0 2016 November 29th, 2016 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: Badami B1-16 Permit to Drill NO: 198-080 API No: 50-029-22880-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Completion Report for Sundry 316-527 for punching the tubing and successfully creating a gas lift type flow. If you have any questions, please contact me at(907) 727-7404. Sincerely, fr , G _ �J Conrad Perry Sr. Vice President Savant Alaska, LLC (a Glacier Oil &Gas Corp. owned company) 10-404 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • . B1-16 Daily Operations Summaries PTD: 198-080/API: 50-029-22880-00-00 11/11/2016 RU Eline. Pressure test lubricator to 2500 psi. RIH with 1-9/16" x 10'tubing puncher(1 spf, 0° phase). Set top shot at 11400' and fire gun (11400'— 11410', 10 shots). POH and verified guns fired. RIH with 1-9/16"tubing puncher loaded with 1 shot. Set shot at 10879' and fire gun. POH and verified gun fired. RD Eline. END of B1-16 Wireline Operations (Sundry 316-527) Bad.B1-16 Current Wellbore Schematic • 11/28/2016 Version-Current r I 1 l' L Tubing Hanger-2 7/8"x 11"EUE 8rd-ID 2.441" Ported for Tandem E,F/Adap 1` 20" 91.1#H40 110'MD j "",, ID-19.124" Buttress 110'TVD - I 2 7/8"KBMG 1"pocket mandrels w/EUE 8rd(BxP)-ID 2.441" SO,1"SBKO 10/64(no pressure set remains open) Heat Trace installed w/Cannon Clamps @ 3,911'MD/3,519'TVD 1 L[. I ,, 9 5/8" 40#L-80 5,377'MD ID-8.681" Buttress 4,600'TVD II' ---- 2 7/8"6.85#L80 BTC Tubing-ID-2.441" Tubing Punch©10,879'MD 2 7/8"Otis X Landing Nipple-ID 2.313"©11,382'MD/8,762'TVD I-- ; II' ....,,,,,,-..- 2 7/8"Otis XN Landing Nipple-ID 2.313"@ 11,397'MD/8,774'TVD 1Tubing Punch @ 11,400'-11,410'MD , (1 spf,0°phase,10 shots) """"'Top of ESP Assy @ 11,423'MD/8,794'TVD ADV WeIlLift Discharge Gauge Unit Discharge Head Pump(x2) 1 Gas Separator w/Adapter Kit 111,11 Upper Tandem Seal Lower Tandem Seal Motor Sensor/Motor Gauge Unit '', Bottom of ESP Assy©11,492'MD/8,853'TVD I l -- 4 1/2"Tubing stub cutoff TOP-ID 4.00"@ 11,529'MD/8,880'TVD HES 7"x 4 1/2"Permanent TNT Packer @ 11,557'MD/8,911'TVD 1f` 'I ``' HES 4 1/2"XN-Nipple 9CR-ID 3.725"@ 11,574'MD/8,924'TVD I 4 1/2"Tubing Bottom(WLEG)-ID 3.958"@ 11,586'MD/8,933'TVD TOL-ID 4.408"@ 11,752'MD/9,078'TVD 7" 29#USS-95 11,928'MD ID-6.184" Buttress 9,287'TVD Perforations MD MD TVD TVD - Top Base Top Base II 12,770 12,828 10,344 10,402 13,080 13,104 10,296 10,319 1, Q 13,130 13,190 10,398 10,456 4 1/2" 12.6#L80 13,372'MD r ID-3.958" BTC-M 10,578'TVD PBTD:13,286'MD/10,494'TVD • • OF Tit \�\�)//7,4 ) THE STATE Alaska Oil and Gas kv Conservation Commission of ALAS KA 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 OF ALASSt Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Sr.Vice President Savant Alaska,LLC 601 W. 5th Ave., Ste. 301 SCANNED MAR 0 22017, Anchorage,AK 99501 Re: Badami Field,Badami Oil Pool,B1-16 Permit to Drill Number: 198-080 Sundry Number: 316-527 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of October, 2016. RBDMS OCT 2 4 2016 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Tubing Punch_❑✓ ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: .,F 4,,f.. L.j-1t SAVANT ALASKA,LLC Exploratory ❑ Development ❑✓ • 198-080 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W 5TH AVE,SUITE 301,ANCHORAGE,AK 99501 50-029-22880-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ B1-16 'REC' IV 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 367006, ADL 367011,ADL 365533 - Badami Unit/ eekit S4A.Z w 0;`, ' ��i 2016 11. PRESENT WELL CONDITION SUMMARY ((����) I /� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): OIa,A1 p. 13372' ' 10633' ' 13286' 10549' 2510 psi None None Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 110' 110' 1530 psi 520 psi Surface 5342' 9 5/8" 5377' 4600' 6820 psi 4230 psi Intermediate 11895' 7" 11928' 9287' 9690 psi 9200 psi Production -- -- -- Liner 1620' 4 1/2" 13372' 10633' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12770'-13190' 10344'-10456' 2.875" L80 11423' Packers and SSSV Type: HES 7"x 4 1/2"TNT Packer Packers and SSSV MD(ft)and TVD(ft): No SSSV installed. Packer @ 11557'MD/8965'TVD 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program 0BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Conrad Perry Email cperry@glacieroil.com Printed Name Title .d Perla - Sr.Vice President Signature / Phone Date 2 907-747-74_04 70,3// COMMISSION USE ONLY Conditions of approval: Notify Commis so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ / �1 Spacing Exception Required? Yes ❑ No gf Subsequent Form Required: 0 — 41 C7 1 RBDMS )yL/ OCT 2 4 2016 APPROVED BY Approved by:047P 9COMMISSIONER THE COMMISSION Date/0 —/L 0 j4v44IkIioAs Form 10-403 Revised 11/2015 slid for 12 months rom the date of approval. Attachments in Duplicate /C-1/-/6 /Q * iS7 - 75/ GLACIER RECEIVED OCT 13 Zu " October 13, 2016 ACC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: Badami B1-16—Tubing Punch Application Cook Inlet Energy: 50-029-22880-00-00 Dear Ms. Foerster, In 2014, Savant Alaska, LLC, submitted an Application for Sundry, 314-418, to plug and abandon Badami B1-16. The abandonment did not occur and the Sundry Approval expired. Savant Alaska, LLC, hereby submits an Application for Sundry Approval for Badami B1-16, PTD: 198- 080. The ESP failed in September 2016. In an attempt to restart production, Savant is requesting permission to punch holes in the tubing at various depths above the failed pump in an effort to create a gas lift type function. If you have any questions, please contact me at 907.747.7404. Sincerely, Conrad �/1/71/Y y Sr. Vice President Savant Alaska, LLC (a Glacier Oil & Gas Wholly Owned Company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 Bad•B1-16 Current Wellbore Schematic 0 4/18/2014 Version-Current Tubing an -2 7/8"x 11"EUE 8rd-ID-2.441" Ported for Tandem E,F/Adap 1'"• 20" 91.1#H40 110'MD ID-19.124" Buttress 110'TVD 2 7/8"KBMG 1"pocket mandrels w/EUE 8rd-ID-2.441" SO,1"SBKO 10'/64(no pressure set remains open) ". '"Heat Trace installed w/Cannon Clamps @ 3911'MD/3519'TVD 9 5/8" 40#L-80 5377'MD ID-8.681" Buttress 4600'TVD 2 7/8"6.85#L80 BTC Tubing-ID-2.441" 1, if / 2 7/8"Otis X Landing Nipple-ID 2.313"@ 11382'MD/8762'TVD �$ ��17Ji_ III 2 7/8"Otis XN Landing Nipple-ID 2.313"@ 11397'MD/8774'TVD ., I """ "a"""Top of ESP Assy @ 11423'MD/8794'TVD j WeilLift Discharge Gauge Unit " "g/f Discharge Head Pump(x2) T Gas Separator w/Adapter Kit a� {ail Upper Tandem Seal Lower Tandem Seal Motor 0 Sensor/Motor Gauge Unit AP-- i i I Bottom of ESP Assy©11492'MD/8853'TVD 4 1/2"Tubing stub cutoff TOP-ID 4.00"©11529'MD/8880'TVD 11111 1 - k HES 7"x 4 1/2"Permanent TNT Packer @ 11557'MD/8911'TVD l HES 4 1/2"XN-Nipple 9CR-ID 3.725"©11574'MD/8924'TVD x 4 1/2"Tubing Bottom(WLEG)-ID 3.958"@ 11586'MD/8933'TVD TOL-ID 4.408"©11752'MD/9078'TVD 7" 29#USS-95 11928'MD ID-6.184" Buttress 9287'TVD Perforations MD MD ND TVD — Top Base Top Base 12,770 12,828 10,344 10,402 13,080 13,104 10,296 10,319 I, 13,130 13,190 10,398 10,456 — 4 1/2" 12.6#L80 13372'MD ID-3.958" BTC-M 10578'TVD PBTD-6,143'MD Belli B1-16 Proposed Tubing Punch • 10/11/2016 • Version-1.0 Tubing Hanger-2 7/8"x 11"EUE 8rd-ID-2.441" Ported for Tandem E,F/Adap ' 11:I 20" 91.1#H40 110'MD P 1 '--,.. ID-19.124" Welded 110'TVD ' 2 7/8"KBMG 1"pocket mandrels w/EUE 8rd-ID-2.441" ' SO,1"SBKO 10'/64(no pressure set remains open) <—"`" " ""Heat Trace installed w/Cannon Clamps @ 3911'MD/3519'TVD 9 518" 40#L-80 5377'MD i ID-8.681" Buttress 4600'TVD 2 7/8"6.85#L80 BTC Tubing-ID 2.441"@ 11423'MD/8794'TVD L, . ti r 4 Tentative:Tubing Punch @—9885'MD ` ITentative:Tubing Punch @—10885'MD 4...................."Tubing Punch @ 11390'MD 1 Tentative:10'of Tubing Punch @ 11385'-11395'MD iu I 2 7/8"Otis X Landing Nipple-ID 2.313"@ 11382'MD/8762'TVD 1 IF; 2 7/8"Otis XN Landing Nipple-ID 2.313"@ 11397'MD/8774'TVD * ."" Top of ESP Assy @ 11423'MD/8794'TVD ' WeIlLift Discharge Gauge Unit Discharge Head Pump(x2) liIGas Separator w/Adapter Kit IIO Upper Tandem Seal Lower Tandem Seal Motor Sensor/Motor Gauge Unit . '1J Bottom of ESP Assy©11492'MD/8853'TVD i• 4 1/2"Tubing stub cutoff TOP-ID 4.00"@ 11529'MD/8880'TVD : Illt ' HES 7"x 4 1/2"Permanent TNT Packer @ 11557'MD/8911'TVD iI HES 4 1/2"XN-Nipple 9CR-ID 3.725"@ 11574'MD/8924'TVD I I 1E1.1 1 4 1/2"Tubing Bottom(WLEG)-ID 3.958"@ 11586'MD/8933'TVD TOL-ID4.408"@ 11752'MD/9078'TVD Iii 7" 29#USS-95 11928'MD ID-6.184" Buttress 9287'TVD Perforations MD MD TVD TVD — Top Base Top Base �, II 12,770 12,828 10,344 10,402 s 13,080 13,104 10,296 - 10,319 I, v 13,130 13,190 10,398 10,456 = 4 1/2" 12.6#L80 13372'MD ID-3.958" BTC-M 10578'TVD PBTD-6,143'MD • • GLACIER 1. WELL NAME— Badami B1-16 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is shut-in. Scope of Work: • Clean out paraffin in tubing. • Tubing punch single hole at 11,390' MD. • Tentative: Tubing punch 10' of tubing from 11,395' to 11,385' MD • • Tentative: Tubing punch single hole at ^' 10,885' MD. • Tentative: Tubing punch single hole at ^' 9,885' MD. General Well Information: Reservoir Pressure/TVD: 0.34 psi/ft 4,257 psi @ 12,497' MD (9,801' TVD)— BHP Survey 11/10/2011 MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.34 psi/ft X 10,456' TVD)—(0.1 psi/ft X 10,456' TVD) = 3,555 psi — 1,045 psi = 2,510 psi Wellhead Type/Pressure Rating: 11" 10M Wellhead —4 1/16" 5M tree BOPE: Rigless—Slickline/E-line Lubricator Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: None Drilling Manager Sr. Drilling Engineer Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program Slickline 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Rig up slickline and test lubricator to 3,000 psi. 3. RIH and clean out paraffin in tubing down to 11,400' MD, if possible. 4. Rig down slickline. E-line Phase 1 5. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 6. Rig up E-line and test lubricator to 3,000 psi. 7. RIH with 1-11/16" tubing puncher and punch %" hole (0° single phase) in tubing at 11,390' MD. 8. Rig down E-line. 9. Turn well over to production for gas lift. E-line Phase 2 (if required) 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first 2. Rig up E-line and test lubricator to 3,000 psi. 3. RIH with 1-11/16" tubing puncher and punch 10 ft of tubing (1 spf, 0° single phase) from 11,385' to 11,395' MD. 4. RIH with 1-11/16" tubing puncher and punch %" hole (0° single phase) in tubing at 10,885' MD. 5. Rig down E-line. 6. Turn well over to production for gas lift. E-line Phase 3 (if required) 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first 2. Rig up E-line and test lubricator to 3,000 psi. 3. RIH with 1-11/16" tubing puncher and punch 'A" hole (0° single phase) in tubing at 9,885' MD. 4. Rig down E-line. 5. Turn well over to production. 3 • • • Schwartz, Guy L (DOA) From: Conrad Perry <cperry@glacieroil.com> Sent: Wednesday,October 19, 2016 4:40 PM To: Schwartz,Guy L(DOA) Cc: Amanda Dial; David Kumar, Stephen Ratcliff Subject: RE: B1-16(PTD 199-080) tubing punch/Gas lift cony Guy, We will be pushing gas down the annulus and taking production from the tubing. Our surface injection pressures will be less than 2500 psi. Bottom hole pressure is 2150 psi. The well previously was on gas lift so hookup should be conventional. They tested the casing down to 2100' with a retrievable bridge plug to 2000 psi in 2012 during the change over from gas lift to ESP. I do not see any other annulus test since the well was put in service in 1998. There is no way to test the annulus now without a workover. conrad From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,October 17, 2016 11:08 AM To:Conrad Perry<cperry@glacieroil.com> Subject: B1-16(PTD 199-080)tubing punch/Gas lift cony Conrad, Can you detail more of your plan to convert well to gas lift using tubing punches. Assume you are using gas lift down the IA to initiate production... What kind of header pressure on gas lift,SVS changes, last casing test etc. ?? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALIIYNOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~'~0 .. (~ ~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other Complete COMMENTS: Scanned b~Mildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission K� Lil(�2(1 3 DATE: August 16 2013 TO: Jim Regg ( / g P. I. Supervisor FROM: Chuck Scheve, SUBJECT: No Flow Test Petroleum Inspector Savant Alaska LLC Badami B1-16 PTD# 1980800 Friday, August 16, 2013: I traveled to the Badami field and witnessed a no-flow test on well B1-16. I arrived on location and found the well being bled off to atmosphere with a maximum flow of 720 scf per hour of gas and no fluid observed. The well was left open to atmosphere - and over a 1 hour period the flow rate diminished to <300 scf per hour. The well was then . shut in and a pressure build up of 5 psi in the first hour was observed on the tubing, no further pressure increase noted over the next two hours. When reopened to atmosphere the pressure dissipated rapidly. SUMMARY: Badami Well B1-16 meets the AOGCC requirements for no flow status. SCANNED iii E ro 4v • • il A ' ' A ' L Li li Li= _ Ir-, -',' / A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANC O HORAGE, ALASKA 99501-3539 PHNE (907) 279-1433 FAX (907) 276-7542 Erik A. Opstad Drilling & Wells q0 ° , Savant Alaska, LLC 1 l-/°. P.O. Box 112212 V a" Anchorage, AK 99511 co‘i ..t6 Re: Badami Field, Brookian Pool, B1-16 ..- --- - Sundry Number: 312-089 Dear Mr. Opstad: tic NOLOA ikii 1 ‘2 2-°12- Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holida or weekend. *re/ ■ o , n . ■ o - .1 n ommissioner DATED this ( day of March, 2012. Encl. • Fisher, Samantha J (DOA) From: Foerster, Catherine P (DOA) Sent: Thursday, March 08, 2012 11:50 AM To: Fisher, Samantha J (DOA) Subject: Re: B1 -16 Approve. Sent from my iPhone On Mar 8, 2012, at 12:53 PM, "Fisher, Samantha J (DOA)" <samantha.fisher @alaska.gov> wrote: > Please approve. > Thank you, > Samantha Fisher, Executive Secretary II > Alaska Oil and Gas Conservation Commission > (907)793 -1223 > <S45C- 212030809432.pdf> 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 2 2012 APPLICATION FOR SUNDRY APPROVALS 20 AaC 25,280 Alaska Ali Gas G01t�, Comtxti�$ 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ AC�ro Prog ram ❑ Suspend ❑ Pii,g Perforations ❑ Perforate ❑ Pull Tubing 0 - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: kw••- ESP (a 2. Operator Name: 4. Current Well Class: 5. Permit to Drill be � �(, 1. Savant Alaska. LLC Development El - Exploratory ❑ / 9 80 0 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 112212 Anchorage, AK 99511 50- 029 - 22880/ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El B1-16 ✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 367006 Badami Unit / Brookian 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13372' 10633 ' 13286. 10549 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 91.1 # H -40 110' 110' 1530 psi 520 psi Surface 5342' 9 5/8" 40# L -80 5377' 4600' 6820 psi 4230 psi Intermediate 11895' 7" 29# USS -95 11928' 9287' 9690 psi 9200 psi Production Liner 1620' 41 /2" 12.6#1-80 top11752' btm 13372' top 9137' btm 10633' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13130' to 13190' 10398' to 10456' 4-1/2" 12.6# L -80 11586' Packers and SSSV Type: Packers and SSSV MD (fl) and TVD (ft): HES 7" x 4 TNT PKR No SSSV Installed (X NIP Available) PKR (§ 11557' M D/ 9881' TV D 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory ❑ Development EI - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 3/10/2012 Commencing Operations: Oil ig - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Erik Opstad or Gary Hammon Printed Name Erik A. Opstad Title Drilling & Wells Signature - '`• 907 -868 -1258 Date March 01,2012 A er I , � COMMISSION USE ONLY �7 0 Conditions of approval: Notify („� Commission so that a representative may witness Sundry Number: �` --OU Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: -,- 3 sof) r %v / )f2 I sf— Subsequent Form Required: /° APPROVED BY � Approved by: CO SIGNER THE COMMISSION Date: Form 10-403 Revised 1/2k tit 3/4 0 R 1 G 1 N A L R 2012 , C)?' 6\710- I • • SAYANT ALASKA Summary of Proposal B1 -16 was spudded by BP Exploration (Alaska), Inc. (BPXA) on May 3, 1998 targeting the Brookian turbidite sand reservoir at Badami and originally designed to be a gas injection well. The well reached T.D. on June 6, 1998 and was completed on August 8 1998. After re- perforating the interval from 13,154' to 13,174' on September 15, 1998, BPXA stimulated the 3-2 and A -5 sands on September 17 The stimulation program seems to have been only partially successful in that the work left approximately 700 -feet of fill atop the perforations. Apparently, BPXA was not equipped to clean out the well and therefore was unable to put the well on production successfully. Records show two periods of brief production in 2006, but neither was sustained. In November 2011 Savant Alaska reentered the well with a coil tubing unit and cleaned off the perforations. About halfway into that cleanout program the well began to flow 21° API crude to tanks at surface. The flow was switched to the production facilities and test separator (see attached report). The well flowed for approximately 36 hours before being unable to buck the first stage separator back pressure of 170 psi. Production was switched to the second stage separator with a back pressure of —80 psi and the well resumed flowing for about 48- hours, but ultimately died. The well then flowed briefly to open top tanks, but that too ceased and the well was shut - in and secured. A Static Bottom Hole Pressure Survey (SBHPS) was run revealing a pressure of 4,260 psi at 12,497' SLM (-9750' TVDss) as attached. 9.`1 Pfd .-titW As detailed in this Application for Sundry Approvals, Savant Alaska intends to modify the well's current design (Schematic 1) by pulling the existing 4 tubing, then rerunning new 2% /s" tubing with an ESP assembly (Schematic 2). We expect the work to take 7 -days and the newly completed well will be place on production immediately. � tf 5�✓ � o � Erik Opstad = 3 Si ( r 5" " Savant Alaska LLC TREE = 4- 1/16" / 5000 PSI / CIW 0 I WELLHEAD = 11" / 10000 PSI / FMC Se1( NOTES: ACTUATOR = B1 KB. ELEV = 54.3' BF. ELEV = 19.0' 11 Ili KOP= Max Angle = T 49 @ 6434' 1 2208' H4 -1/2" HES X NIP, ID = 3.813" I Datum MD = Datum TVD= 19 -5/8" CSG, 47 # #, L -80 BTC, ID = 8.681" H 6377' ORIGINAL CONFIGURATION Minimum ID = 3.725" @ 11574' 4 -1/2" XN NIPPLE B 11557' H7" X 4 -1/2" HES TNT PKR, ID = 3.875" I • 1 11574' I -14 -1/2" XN NIP, ID= 3.725" I 4 -1/2" TBG, 12.6 #, L -80 NSCT, --I 11586' I--- I 11586' I- I4 -1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" H ELMD TT NOT LOGGED I . �I 11752' 1-17" X 4 -1/2" LNR HNGR PKR, ID = 4.408" I 17" LNR, 29 #, USS -95 BTC, ID = 6.184" H 11928' I A ■ I PERFORATION SUMMARY REF LOG: SBT ON 08/05/98 I ANGLE AT TOP PERF: 20 @ 12770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE I 12770 - 12828 FRAC'D 09/04/98 13080 - 13104 FRAC'D 09/04/98 13130 - 13190 FRAC'D 08/09/98 / 1 PBTD I--I 13286' 1 7.v.w4 4 -1/2" LNR, 12.6 #, L -80 BTC MOD -1 13372' ■•WAtt! .0152 bpf, ID = 3.958" DATE REV BY COMMENTS 1 DATE REV BY COMMENTS BADAMI ? ? ?? ORIGINAL COMPLETION , WELL: B1 -16 04/06/99 DDW UPDATE INFORMATION 1 PERMIT No: 1980080 08/30/06 WRR/TLH FORMAT CORRECTIONS API No: 50- 029 - 22880 -00 SEC TNRE i BP Exploration (Alaska) 1 B1 -16 Monthly Production Cum Oil Prod 8,037 10000 - — Originally a Gas Injection Well No gas lift mandrels in tubing string • Horizontal workover candidate 1000 -- • IN 100 • • 10 - - - - -- ♦ • • • • Ne \\�� ,\\°'§ �\ �� e ,,. �\�,� 5, � O �y � z pt ' bt z h 'NO /// 4 61 �\c,41, � � � � �� �� � �� �� �� �� 4 Date -4-Oil (bbls)1 -U-Gas (MCf) • Days On • 22- Nov -11 19:38:25 RPT020: well Test : Demanded : Page 1 WELL TEST RESULTS + 22- Nov -11 19:38:25 ERROR MESSAGES RELATING TO FREE FORMAT REPORT 020 Line 40: F 26 WT- CURR- AVG -WTMP PV F6.3 * ** ERROR 13 * ** DATAIO ERROR = 823E WELL TEST REPORT • WELL SLOT 16 �JZS / re T 4 c40,4/V-007 DESCRIPTION VALUE Test Month /Day /Year 11/ 22/ 2011 Test Start Hr:Min 16: 19 Purge Duration (Hrs) 1 Test Duration (Hrs) 4 Test Type 2 BOARD INFORMATION Slot Number (B1 -xx 16 Choke setting (64ths) 104.000 Avg Well Head Press (PSI) 174.915 Avg well Head Temp (Deg F) 1591.342* Calc oil Flow (BPD) 189.616 Calc H2O Flow (BPD) 0.364 Produced Gas Rate ( MMSCFD) 0.006 - 0.000 Calc Gas Lift Rate (MMSCFD) 0.000 Calc Gas /Oil Ratio (SCF /STB) 28.801 Calc Sep GFR (BPD) 189.961 Total Gross Fluid (BBLS) 31.660 Calc sep Gas Flow ( MMSCFD) 0.006 Net Oil Total 31.603 Avg separator Press (PSI) 171.021 Avg Separator Temp (Deg F) 77.942 Avg water Cut CO 2.187 Manifold Press (PSI 173.279 Gas Lift Press (PSI -6.198 Gas /Oil Ratio Manua (SCF /STB) 21030.000 Gas /Oil Ratio Method 0.0 H2O Cut from Analyzer ( %) 2.1 H2O Cut Manual Op H2O Cut Method 1.0 WELL TEST COEFFICIENTS QM 190.0 Po 2001.0 n 6.0 PRO FO• ESP LIFT WELL DESIGN FOR BADAM•LL B1 -16 Drill Floor to Sea Level 54.3 referenced to Nabors Rig 28E Drill Floor to Tubing Hanger 32.3 referenced to Nabors Rig 28E OD ID Weight Length MD TVD Ground Level to Sea Level 19.0' Wellhead 11 "/10,000 psi - FMC inch inch Lbs /ft ft DF ft Tree 4- 1/16" / 5,000 psi - CIW Tubing Hanger 2 7/8" x 11" EUE 8rd Ported F /Tandem E, F /Adap 4 L Conductor 20.000 19.124 91.1 80 118 GL Station 1 11 I 2 7/8 KBMG 1" pocket mandrels w /EUE 8rd BxP 150 1 ^I! 4 2 -7/8' 6.5 #, L EUE 8RD Tubing 4.50" 3.958 12.6 @ 13° A L. 9 -5/8" 47# L BTC @ .0732 bpf 9.625 8.681 47 534 4600 @ 50° Max. Point of Deviation 5252 11200 8677 • • 2 -7/8" OTIS X Landing Nipples 11300 8754 *• @ 33 2 -7/8" OTIS XN Landing Nipples 11420 8833 2' PUP joint w /Cannon Mid -Joint MLE/TEC Clamp 10 I Note: ESP Assembly 69.76' (in Catalog Length) ADV (Automatic Diverter Valve) 98 11428 8835 2' PUP joint w /Cannon Mid -Joint MLE/TEC Clamp 10 Well Lift Discharge Gauge Unit 40 2' PUP joint w /Cannon Mid -Joint MLE/TEC Clamp 10 @ 33° Discharge Head 13 Pump 860 Gas Seperator 260 Upper Tandem Seal 267 Lower Tandem Seal 267 Motor 1209 Sensor Pack 59 V Bottom of ESP (Centralizer) 8 11498 8911 Top of cutoff 41/4" tubing stub 11527 8940 HES 7" x 4 -1/2" Permanent TNT Packer 5.875 3.850 7.1' 11557 8965 HES 4.5" XN- Nipple 9CR ID 3.725" 4.500 3.725 11574 8978 Bottom of original 4'/ : :" tubing (WLEG /EOT) 4.500 3.958 11586 8987 7" x 4 -1/2" Liner Hanger Packer 6.055 4.408" 29 11752 9133 P 7" 29 #, USS-95 Casing @ .0371 bpf 7.000 6.184 @ 27° 7" 29# USS - BTC Casing Shoe 7.000 6.184 11928 9287 • 4 -1/2" 12.6# L -80 BTC -M Liner @ .0152 bpf 4.5" 3.958 12.6 1621 11752 9133 1 1 J -2 Sand Peforations 12770' - 12828' 110344 - 10402 TVD] 3 -3/8" guns ® 6 -SPF, Frac'd 09 -17 -98 1 1 A -5 Sand Peforations 13080' - 13104' ]10296 - 10319 TVD] 3 -3/8" guns @ 6 -SPF, Frac'd 09 -17 -98 1 ! A -5 Sand Peforations 13130' - 13190' [10398 - 10456 TVD] 3 -3/8" guns @ 6 -SPF & 2'4" Guns @ 6 -SPF Frac'd 09 -17 -98 - @ 13° PBTD 4 -1/4" 12.6# L -80 BTC -M Liner @ 0.0152 BPF 4.500 3.958" 12.6 I No. Rev. by Comments /Date B1 -16 ESP Design 1 E. Opstad Initial Well WorkoverDesign, Version 01 -03 -2012 Badami Unit 2 R. Berube ESP Assembly and Revise Borehole Jewelry 02 -22 -2012 API No. 50- 029 -22880 3 E. Opstad Final Edits & Review 02 -23 -2012 Permit to Drill # 98 -80 03 -10 -2012 SWAM' - - ALASKA . • BA %I ESP Assembly Schematic KER WOKS milmehruir Well: B1 - 16 Date:02/03/2012 Coordinator: PatteyParker renirilii Joint PP MEC - -_ -- Clamp plitC. 1 Upper Tandem Seal I c��o� - Automatic Divener Valve t Piry Model GSB3DBUT SB /SB PFSA Threads 2 -7/8" EUE 8Rd. (Box /Pin) Diameter 5.13 inches Diameter 4.5 Catalog Weight 267 inches Feet Catalog Weight 98 Catalog Length 6.90 Catalog Length 3.00 Tally Length 1 a ny Lengtn - WellLift* o q SIN C anon Pedolo Discharge Gauge Unit = Cannon MdJO M c omp P/N I Ca mton PM'';''- cnaP Threads 2 -7/8" EUE 8Rd. (Box/Pin) Lower Tandem Seal Diameter 4.5 Model GSB3DBLT SB /SB PFSA CL5 Catalog Weight 40 Diameter 5.13 Inches Catalog Length 1.91 Catalog Weight 267 Pounds Feel PUP Tally Length Catalog Length 6.90 pim�n Discharge Head - pe,E�, !ally auy Lengtn "" . ,17 Model GPDIS I c o pn Pmt =zers JIM Threads 2 -7/8" EUE 8Rd. fl 1-'/N I Catalog Weight 13 - – Catalog Length 0.50 Tally Length Motor ..1pL1ZE PIN 38383 Model KMH Horsepower 190 Pump Voltage 2415 I Type 137 -P17 Amperage 48 +111311 J/N Model Diamet SXD Diameter 5.62 Inches e 5.38 Catalog Weight 1209 Pangs Catalog Weight r 860 Catalog Length 16.80 Feet Catalog Length 18.90 Tally Length I ally Lengtn SIN P/N tI — .Sensor U Gas Separator Model WeIILift MGU Model GRSFTX AR He (400 internals) Diameter 4.50 Inches Diameter 5.13 Catalog Weight 59 Pounds Catalog Weight 260 Catalog Length 3.80 Feet = Catalog Length 4.95 Tally Length laity Lengtn J/N J/N Y/N YIN Centralizer 1 Diameter 5.85 Inches Catalog Weight 8 Pounds Power Cade —11,600 of #1 CELR SS Catalog Length 2.10 Feet Heat Trace Cables 3500' of #8 AWG Tally Length Cable 1 nformation: Total Assembly Catalog Weight 2986.00 Pounds Cable Information: Total Assembly Catalog Length: 69.76 Feet Cable Information: Maximum Assembly Diameter: 5.85 Inches Motor Lead SM: Total Tally Length: Feet Motor Lead P /N: CUT to .020P BI-10 Uwe.e E.UT..m o.,,m • • ;� Baker Hughes Incorporated BAKER 795 East 94th Avenue HUGHES Anchorage, AK Project: Pump: 137- 538P17SXD Customer: Savant - Gary Hammon Seal: GSB3 DB [513Series] Well: B1 -16 Motor: KMH 190HP 2415V 48A [562Series] Engineer: Brad Yingst Cable: #1 CELR 5kV ,11425ft Controller: VSD 4500 -VT 519kVA/ 480V/ 624A NOTE: Motor ratings at 60Hz Comments: Case 1 = 190HP Likely Production 137- 538P17SXD HEAD (ft) 65 Hz 10000 ■ 60 Hz ' ` IL 8000 rimiva 6000 50 Hz / 45 Hz 4000 • 40 Hz miralOptik Ilan A 2000 o-441 A 500 1000 1500 2000 2500 3000 Flowrate (BPD) AutographPC V8.3 File:B1- 16.apcx ©Copyright 2012 Baker Hughes Inc. All Rights Reserved • • Baker Hughes Incorporated BAKER 795 East 94th Avenue HUGHES Anchorage, AK Input Parameters: Fluid Properties: Gas Impurities: Oil Gravity = 21.14 °API N2 = 1.0 % Water Cut =0% H2S =0.8% SG water = 1.02 rel to H2O CO2 = 1.0 % SG gas = 0.65 rel to air Formation GOR = 60.0 scf /STB Bubble Point Pressure Bot Hole Temp = 188 °F PB = 368psia Surf Fluid Temp = 90.0 °F Inflow Performance: Target: Datum = 10359 ft Pump Setting Depth Perfs V. Depth = 10344 ft (vertical) = 8910 ft Datum Static P = 4260 psi Desired Flow = 1200 BPD Test Flow = 190 BPD Gas Sep Eff = 75.0 % Test Pressure = 3800 psi Tbg Surf Press = 170 psi PI = 0.413 BPD /psi Csg Surf Press = 200 psi IPR Method = Composite IPR Casing & Tubing: Roughness = 0.0018 in Casing ID (in) 6.184 4.0 4.0 Tubing ID (in) 2.441 Vertical Depth (ft) 8910 9156 10359 Measured Depth (ft) 11495 11782 13089 Correlations PVT: Dead Visc: Saturated Visc: UnderSaturated: Gas Visc: Glasso Beggs & Robinson Vasquez & Beggs Lee Oil Compress: Formation Vol: Z factor: Bubble Point P: Vasquez & Beggs Standings Hall & Yarborough Standings Correlations Multiphase: Tubing Flow: Hagedorn & Brown Casing Flow: Hagedorn & Brown Comments: Application Severity: Benign Normal High Severe Extreme Temperature Abrasives Corrosion Gas AutographPCTM V8.3 File:B1- 16.apcx ©Copyright 2012 Baker Hughes Inc. All Rights Reserved • Baker Hughes Incorporated BAKER 795 East 94th Avenue MOINES Anchorage, AK Operating Parameters / Selection: Design Point: Desired flow (total) = 1200 BPD Frequency = 57.8 Hz % water = 0.0 % GOR into pump = 59.19 scf /STB % Gas into pump = 0.4 %GIPbs /0.1 %GIP TDH = 7577 ft Friction Losses = 96.51 psi Puma Selection: Intake Discharge Pump Selected: Pressure = 804 psi 3707 psi CENTURION 137- 538P17SXD Flowrate = 1284 BPD 1257 BPD Pshaft RPM = 3389 Specific Gravity = 0.874 rel -H2O 0.893 rel -H2O Shft HP @ 57.8 Hz = 120 Viscosity = 8.597Cp 15.06Cp Shaft load =(Std 34 %) / (HS 23 %) Required Motor HP at 60.0 Hz = 138 AR 1:1 Pump, High Strength Shaft in LT Seal Selection: Well angle (set depth) = 39.18Deg fm vert. Oil temperature at thrust chamber = 335 °F Sand present Chamber Cap Used (Top to Bot)= Pump uses floater -type stages 50% 43% 63% Motor /Seal Oil type = CL6 Thrust bearing load =29 % Seal Selected : GSB3 DB [ 513 Series] Shaft load = 28 % Options : HL Premium Face Seals, Three Chamber Bag /Bag /Lab Motor Selection: Terminal Voltage = 2151.7 V Fluid Speed = 2.155fUs Motor Current =36.8 A Eff /PF =86.01% / 84.91% Load acc to N.P. =72.4 % Internal Temp =355 °F Shaft Load =14.4 % Motor Selected: KMH 190HP 2415V 48A [562Series] Elevated Motor Internal Motor Temperature Calculated 315 °F CL -6 Motor Oil Required `NOTE: Motor ratings at 60Hz Cable Selection: Surface Length = 140ft Wellhead Voltage = 2265.5V Tubing Length = 11425ft Wellhead kVA = 144.5kVA MLE length = 70.Oft Voltage Drop = 113.8V Surface Temp = 90 °F Cond Temp (main) = 184 °F Temp Rating = 450 °F Surface Cable Main Cable MLE Cable #1 CPNR5.0kV 140ft #1 CELR5.0kV 11425ft #4 MLE- KLHT5.0kV 70.Oft High Temp Lead Jacket Stainless Steel Armor #1 AWG Round Controller Selection: Input kVA = 133.0kVA Voltage Input = 480V System kW = 127.7kW Max Well Head Volts = 2266V Max Ctrl Current = 173.8A Max Frequency = 57.8Hz (8.31V/Hz) Start Frequency = 10.0Hz Step -up Trafo = 4.72 ratio Selected: VSD 4500 -VT 519kVA/ 480V/ 624A AutographPC V8.3 File:B1- 16.apcx ©Copyright 2012 Baker Hughes Inc. All Rights Reserved • • MAI Baker Hughes Incorporated BAKER 795 East 94th Avenue MOM Anchorage, AK Monitoring & Automation Downhole Sensor Selected: WeIILift 700 P /N: C902928 Metallurgy:STAINLESS STEEL Sampling: 22.0 sec /sample Details: Intake Pressure: Range =15.0 to 5000 psia • Accuracy= +/- 5.0 psia Resolution= +/- 0.1 psia Limit =7500 psia Discharge Pressure: Range =15.0 to 5000 psia Accuracy= +/- 5.0 psia Resolution= +/- 0.1 psia Motor Temperature: Range = -40.0 to 500 °F Accuracy= +/- 4.68 °F Resolution= +/- 0.18 °F J -TYPE THERMOCOUPLE Intake Temperature: Range =86.0 to 302 °F Accuracy= +/- 1.8 °F Resolution= +/- 0.18 °F Discharge Temperature: Range =86.0 to 302 °F Accuracy= +/- 1.8 °F Resolution= +/- 1.8 °F Vibration: Range =0 to 9.0 g Accuracy= +/- 0.09 g Resolution= +/- 0.002 g Current Leak: Range =0 to 15.0 mA Accuracy= +/- 0.2 mA Resolution= +/- 0.01 mA AutographPC V8.3 File:B1- 16.apcx ©Copyright 2012 Baker Hughes Inc. All Rights Reserved 13 5/8" 5000# WP HYDRIL, TYPE "GK" 13 5/8" 5000# WP 4'-61" LATCHED TOP BY 2 13 5/8" FLANGED BOTTOM ANNULAR BOP 5 4 1/2" LENGTH ■d PIPE RAMS 111 ■ 13 -5/8" 5000# .1 4' -10 FLANGED HYDRIL 8 DOUBLE GATE PREVENTOR 3" 5000# HCR VALVE ■d SHEAR /BLIND Dm 58 1/8" LENGTH 17' -114" - - 3" 5000# HCR VALVE 1' -10" 3" CHOKE LINE --- - _ 1 `1,i -4 - - -- III40.4II�= -- - --_ KILL LINE - ------ /" 3'x 2 J / L 3" 5000# GATE VALVE 2' -91» 3" 5000# GATE VALVE PIPE RAMS /8" HYDRA ULIC 13 RA( 5 SINGLE 5k PSI GATE GA FLANGED CONNECTION 36" LENGTH J L- 1' gI�IK�� r T J L � 2' 04" --1 r l ) l 1 0} • + 1 NABORS ALASKA RIG 7ES BOP STACK CONFIGURATION Nobon Aka ON99 bc. O � � 2525 C 9TAet sw,. 200 .I /MI/IrO� AncMm AImMa 99503 -2639 907 -263 PMai NABORS ALASKA RIG 7ES Th6 RIG 7E5 BOP STACK CONFIGURATION E ALSTON MEMO BY Arrnvrtn e! L PD. 1Kffft! - SC. ONE 0". arr. Oat W. V + N/A JAN. 2004 7LL0302 1 of 1 MO Nabors Alaska Drilling Rig - 7ES 0-0 are ir • Material List Item Description is A 3 -1/8" 5000# Remote Hydraulic Q,. Operated Choke O B 3 118" 5000# Adjustable Choke 1 -14 3 -1/8" 5000# Manual Gate Valve e iiillik 15 2- 1/16" 5000# Manual Gate Valve To Mud /Gas , ■� Separator Al R , • 41. O • +' �.-'" i" To Secondary ® r'O Choke Line A ` : 11, I. In Cellar ■ • m ,` i Legend aL White Handle Valves aQ Normally Open Red Handle Valves Normally Closed Choke Line a • • Date: 10 -18 -02 Rev. 3 From BOP • ADDITIONAL INFORMATION 1. MUD LEG I.D. 10" I•D• 2. TOTAL LENGTH OF U -TUBE PIPING 34 L.F. 3. TOTAL NUMBER OF BENDS IN U -TUBE 6 TOTAL 4. ANGLE OF BENDS IN U -TUBE (45,90,180) 5 ®90° - 1 © 45° 5. VENT LINE HEIGHT ABOVE GROUND LEVEL 43 1/2" 6. VENT LINE I.D. 10" I.D. 17 -8i" I Nabors Alaska A NABORS INDUSTRIES Company NABORS RIG 7ES MUD GAS SEPARATOR PRODUCED BY: JOE ALSTON SEPTEMBER 6, 2005 Hp I' , 8 ' -6 " 129.25 I.D. U -TUBE PIPING 90° 90° 90° ■ FROM CHOKE 3.438" I.D. - 16' -5" 45° 7 ' -1 4 " 4 11' -1" 90 90 a ENT la' 5 FROM PRv FUEL t _ a LEGEND z' :PHON "' ��"�`� TANK POORBOY — DEGASSER 1 FROM l ‚XI BUTTERFLY VALVE N UM , L ®I III , L A — I H._ l, VALVE I ���� 3" 3' MUD GUN w/VALVE i <F® ��_�� 11 8' SUCTION VALVE DRECO STYLE c/w O 2" ,M' 2" P -TRAP BOLT ON FLAT RUBBER SEAL. VENT FLOW LINE , , �� I RECESSED MUD DITCH GATE C — V 7 DRAG CHAI _ AV Ar AU AU Av A% , Ad SOLIDS I MUD DITCH 1,17--N MUD HOPPER • DISCHARGE S . ,� . 8• 8' ^ 8. DESILTER A TRIP CHEMICAL BARREL 10 HP AGITATOR e _ PILL PIT � TANK �e,�.��- 1 50 BBL CENTRIFUGE 167 BBL _ `eV TANK �`�w — 1 � ► � I I I B� FROM ����� TANK l��'` BURGESS 50 BBL cm__,-,_____ 5 HP AGITATOR L. EQU. BLOWANK 167 BBL ® = 1� O BURGESS ER 10" EQUALIZER I a O lr T IIIIIII +4—L. EQU. / PULSATION DAMPER III 12' DESANDER O® O® — WIER . DEGASSER [ND TANK V PRESSURE INDICATOR PI 6WAC0 518 I � SF600 ® . 12 . 518 167 BBL PRESSURE SWITCH 1 O `, g �l ¢° RELIEF VALVE O 10111P1 6 • ROW ARROW r il 8" • • Z8' 8° " PUMP KEY P/ m HOLE MANWAY Q DISCHARGE SUCTION TANK ® �� ou �7 3 FILL LINE PT - CHARGE /MUD MIX 6x5x14 (14" IMP) 60 HP 160 BBL Z POSSUM BELLY GUILLOTINE GATE ESE 3 6' L6' 6' 6° 3" 2" P2 - CHARGE /MUD MIX 6x5x14 (14' IMP) 60 HP P6 5. ��� S` 1 3 " 3" Z3" Z3" P3 - MUD MIX/TRANSFER 6x5x14 (14' IMP) 60 HP d f Pt0 P4 - DESILTER 6x5x14 (14' IMP) 100 HP • n P5 - DESANDER 6x5x14 (14' IMP) 100 HP � ' � BRINE 250 250 250 P6 - CENTRIFUGE SWACO TYPE 11 VI- o © 00 BBL BBL BB TANKS O © O P7 TRIP TANK 322x13 (13' IMP) 20 HP I MP 2 00 MP 1 OO❑O #. 00 ■ ∎ 00 . P8 - BRINE GRINDEX 8 HP 'N' IMPELLER s CE T- Z CE 4" F-1000 z F-1000 n 3" P9 - BRINE GRINDEX 8 HP 'N' IMPELLER 111 ow oa III- P10 - BRINE GRINDEX 8 HP 'N' IMPELLER - SEE PAGE 2 of 2, HIGH PRESSURE MUD SYSTEM A PRONOUN: OC6w rums N Or ALASKA. RBXmJCWON OR USE OF DES. 6 REMISSIBLE DAY W WPM= W 6161XS Pt 6.6DS ALASKA _ Note" Noteers Alaska Drilling Inc. 0 Nabors Alaska 2525 C Street Suite 200 n NABORS ALASKA RIG 7ES C -- 907- 63 Na ka 9003-2639 - 907-2 -6000 8 PRm600 NABORS ALASKA DRIWNG RIG 7E5 MUD SYSTEM SCHEMATIC MU MUD PROCESS FLOW SCHEMATIC O DRAWN BY as CKEMED 61 JAW APPROVED BY JAW REV. 1 I DA' 1 I I VI CESCRIPRON SCALE Nts DATE MO 2002 MO NO 007.016.dxg 1 of 2 SA /ANT • General Information Permit to Drill #: 198 -80 API #: 50- 029 -22880 Geometry: 20" @ +110' Conductor - existing 9 5/8 " @ 5,377' MD Surface casing- existing 7" @ 11,928' MD intermediate casing - existing 4'/" Liner@ 13,372'MD Top of 4'/" Liner @ 11,752 MD'- existing PBTD @ 13,286' MD 4'/2" Tbg. tail @ 11,586' MD Tubing- existing 4 1 /2" XN Nipple @ 11,574' MD Objectives: No Accidents! No Spills Cut & Retrieve 4 1 /2" Tubing Clean out 7" casing to 4 %" Cut Off Tubing stub © —11,527' MD Run newly inspected 4 1/2" Tubing Completion Assembly with packer, GLMs, SCSSV Turn well over to Badami Production Facility to be put on gas -lift Tubular Pressure Ratings: OD Wt Grade Conn CpIg OD ID Drift Collapse Burst Tensile (in) (Ppf) Type (in) (in) (in) (psi) (psi) Yield (kips) 4- 1/2" 12.6 L -80 NSCT 5" 3.958 3.833 7500 8430 288 Workover Dimensions and Strengths: Pipe Wt (ppf) Grade Conn TJ OD TJ ID Tube ID Max MU TJ Recommended Type (in) (in) (in) Torque Torsional Max Pull (ft -lb) Yield w /new pipe (ft-lb) (kips) 4" DP 15.7 S -135 HT-40 5.125" 2.688" 3.24" 14100 to 37200 583 20200 4" 29.7 HVYWATE HT -39 5.125" 2.68" 2.56" 12900 32800 407 HWDP to19300 Contacts: Individual Title Name Office Home Pager /Cell Drilling Manager Gary Hammon 907 -868- 425 - 868 -3001 206 - 963 -6151 1258/ext 105 NS Cell 907 -448- 6011 General Manager Erik Opstad 907 - 868 -1258 907 - 345 -6346 907 - 244 -5210 ext 101 NS Cell 907 -448- 6010 Page 2 of 8 SAVANT • • HSE Manager Steve Rog 907 - 868 -1258 907 - 345 -0022 907 - 250 -1734 Ext 106 Drilling Supervisor 907 - 868 -1258 256- 307 -1240 256- 307 -2147 Ext 105 NS Cell 907- ' 448 -6011 Exploration Greg Vigil 720 - 328 -7184 303 - 660 -6532 720 - 363 -1041 Mgr. /Completions Engineer CTU & ELINE WORK PRIOR TO ARRIVAL OF NABORS 7ES 1. Obtain needed well work permit from Control Room. RU CTU. Using diesel, test Lubricator to 2000 psi. 2. RIH to make tag run inside 4 1 /2" liner. PBTD is 13286' & bottom perfs is 13190'. If warranted clean out FILL as needed. Use 9.4 ppg NACL brine water for cleanout and /or displacement of all crude oil from liner & tubing. This brine weight will overbalance last recorded SBHPS by some 660 psi. NOTE: Bring sufficient bbls heated pre -mixed brine from Baroid mud plant in Deadhorse heated to 140 deg. F. Total hole volume is 206 bbls from surface to PBTD. Minimum tubing ID is 3.725" thru XN nipple @ 11574'. 3. If cleanout of fill is NOT required, then proceed to displace liner & 7" casing volume (i.e. 30 bbls) up to bottom of tubing @ 11586' with the 9.4 ppg NaCI brine water. Pull CT to 11586' & using brine, jet wash tubing @ pump rate of 1 BPM while POH @ 70 FPM (linear capacity of tubing is ✓ 66' /bbl) to surface. While pumping, hold 500 psi back pressure with choke on tubing while POH to prevent anymore crude from flowing into well. Notify Control Room of pump rate & when starting or stopping pump. Will be taking returns down flow line & holding back pressure with choke. Note: The p urpose of this step is to remove all crude oil from tubing to facilitate Eline beinq able to jet cut tubing after CTU work is completed. Have at least 40 bbls diesel on hand. Entire tubing volume is 176 bbls. 4. After jet washing of tubing to surface, RIH to 2300' to displace tubing & flowline with diesel. Hold 500 psi back pressure with choke while displacing. POH. Shut well in. RD CTU. NOTE: Leave well shut -in & Bring in E -line Unit 5. Obtain needed well work permit from Control Room. MIRU HES Eline unit. Using gas lift gas, pressure test lubricator to 1500 psi. Hold Safety /Pre -Job meeting with HES crew, Savant HSE & Operations Support. RIH with RCT (radial cutting torch) as described below. Page 3 of 8 SAVANT NOTE: According to 1998 well records, the IA contains 2300' MD of diesel on top with 9257' MD of 8.4 ppg 2% KCL water from 2300' to top of packer @ 11557' MD. With the diesel & 9.4 ppg brine that CTU work left in tubing, this would provide a differential pressure from tubing to IA of some 400 psi. Therefore, apply 400 psi surface pressure to IA / using diesel in order to get tubing & IA in equilibrium prior to firing the RCT. Do not ✓ allow any flow back from either tubing or IA during this procedure. 6. With AC powered instrumentation off and Safety Switch Key outside truck, arm HES RCT with RF Secure detonator. 7. RIH with RCT assembly. After depth of 200 -ft has been reached, the Safety Switch Key can be used to restore AC Power to unit; continue to RIH. NOTE: Be sure jars are run along with RCT assembly due to the fact that the 4 %" tubing will likely "off -set" upon cutting & jars may be needed to retrieve RCT assembly. The hole angle at cut depth is 32 degrees. Tie in to collars and /or gamma ray using log and confirm tie in with final correlation pass. Log into cutting position and then stop winch. Confirm with company man that tool is at desired cut depth approximately 30' ABOVE -1491. (i.e. 11527') completion packer (See differential pressure comment above) 8. Apply power for tubing cut. Record any pressure change on tubing & IA. POH when S 3J complete. Close MASTER valve on TREE. 9. RD E -Line unit. 10. Bleed IA to "ZERO ". In bleeding IA any tubing pressure should also go to "ZERO" due to 7 differential from tubing to IA . 11. FMC to install BPV in tubing hanger using lubricator if needed. 12. Have Badami CPF personnel remove Well House & flow lines from both B1 -16 & B1 -15. Page 4 of 8 SAVANT • ALLISKA Nabors 7ES RIG WORK 1. Be sure all containment spill liners for rig footprint are in place. MIRU Nabors 7ES on B1 -16. Record DF distances to gravel pad & tubing head flange on morning and IADC tour sheet reports. The recorded DF to sea level on well during initial drilling was 54.3' to MSL (GL 19' above MSL. DF 35.3' to GL). Nabors 7ES DF is comparably 28' DF to GL. Therefore all currently existing DP & tubing measurements referred to in this plan are in reference to a DF to GL of 35.3' which equates all such depths with Nabors 9ES will be encountered 7' higher. Post AOGCC permits and SPCC plan in the Doghouse. • Notify AOGCC for nipple up & pressure test of 13 -5/8" 5K BOPE. AOGCC notifications ✓ remain the same as development drilling requirements. • Notify AOGCC Slope Inspector @ 659 -2714 or 659 -3607 (pgr#) at least 48 hours in advance. • Prior to workover operations, a safety meeting should be held with the rig crews to discuss procedures. Suggested topics include: - Hole fill calculations with various sizes of pipe and tubing - Well control procedures - Proper tripping practices- incl. complete & accurate trip sheets for all trips! - Flow rates and hole cleaning - Correct and accurate documentation of all BOP tests and safety drills • An 'Accumulator' drill should be held with rig crews prior to operations. Document drill and record on morning report. • Shut -in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. • Trip sheets must be completed and submitted to the Savant Drilling Supervisor after each trip. • The trip tank system should be checked for leaks prior to spud. Confirm that all trip tank gauges are calibrated and working properly. Make sure that all crews understand how to utilize and interpret the trip tank system on Nabors 7ES. • All drills shall be performed and documented as per the written procedures listed in the current 'Drill Expectations and Procedures'. Type of Drill Minimum Frequency* Additional Guidelines Kick During RWO Once per week per crew Kick While Tripping Once per week per crew Well Kill Twice per year per crew Prior to commencing RWO and /or immediately after Stripping Drill. Stripping Twice per year per crew Accumulator Drill Prior to commencing RWO In conjunction with AOGCC BOP test Page 5 of 8 • • SAVANT ALASKA (see details in written procedures) Fire Once per two week tour per crew Spill Once per two week tour per crew H2S (Hydrogen Sulfide) Once per quarter per crew Confined Space Entry Once per quarter per crew et Njg OTE: The tubing is full of diesel from surface to 2300' & 9.4 ppg NaCI brinerom there down to tubing cut (&,, 11527'. The IA has both diesel & 8.4 ppg 2° KCL water in it creating a differential pressure from ' tubing to IA of approx. 400 psi. Have FMC inspect service & repair XMAS TREE as required after ND r tuse to ensure Tree is ready to he re- installed after RWO is complete. ` � 1 , �.t. % 2. Bleed any pressure off TREE. Have FMC install blanking plug in top profile in tubing hangar. ND TREE. Top flange on tubing head is 11" 10K. Using . a 13 5/8" 5K x 11" 10K DSA (in Savant stock), NU 13 5/8" 5K BOPE with 4 1/2" rams installed & test same to 5000 psi per AOGCC regulations. After testing blind rams, choke line & manifold, have FMC pull blanking oluq from tubing hangar. Top thread on tubing hangar is 4 NSCT. Using 4 IBTM box x A° NSCT pin crossover with jt R�(� of 4 1 /" IBTM tubing, screw into tubing hangar for testing of 4 1 /2" rams & hydril. After all BOPE 1 testing complete, have FMC pull BPV. ''✓✓ `"''' "" • Notify AOGCC 48 hours prior to performing BOPE test • Per AOGCC requirement, all stack tests will have a low 250 psi and a high 5000 psi test (against test plug). Each test will be held 10 minutes. • The AOGCC requires a BOPE test every 7days. The AOGCC has indicated that they will be somewhat flexible with this requirement, but the Slope Inspector must be contacted and consulted regarding the seven day test 48 hours before testing. • A'Stripping' drill should be conducted with rig crews. Document drill and record on morning report. ✓ • A 'Well Kill' drill should be held with rig crews. Document drill and record on IADC report. • A well kill sheet shall be p d in t doghouse and updated each tour. / With AMS closed, pump 40 bbls diesel down tubing thru tubing cut @ 11,527' aking returns from IA. Attempt to salvage the 2300'of diesel (i.e. 40 bbls) on top of IA. After diesel from IA is recovered, then pump 75 bbls 9.4 ppg hot NaCI brine down IA recovering the 75 bbls diesel from tubing. After diesel from tubing is recovered, then begin to circulate the 9.4 ppg NACL brine down tubing taking returns from IA until clean 9.4 ppg NACL brine is coming from IA. Catch & dispose of the approx.161 bbls of the old 8.5 ppg 2% KCL water from IA. Continue to circulate until all of old 2% KCL water is recovered & clean NaCL water returns are to surface. Continue to circulate for 6 hours to warm up wellbore. Until all diesel & the old 2% KCL is recovered, hold 200 psi back pressure through choke manifold in order to prevent any crude from perforations from flowing into wellbore. Once clean 9.4 ppg NaCI brine is coming from IA, there will be NO NEED to continue holding any back pressure. With a full column of 9.4 ppg brine the production formation should be overbalanced by some 660 psi compared to the last SBHPS of 4260 psi. NOTE: Bring sufficient bbls of 140 °F water from Prudhoe Bay Hot Water Plant to mix 9.4# NACL water on rig in order to displace entire hole volume + keep just enough in pits to circulate with. Will need at least 52 bbls NACL brine water to fill hole when 4 %" tubing is pulled. Page 6 of 8 • • SAVANT ALASKA 4. Monitor for any pressure build -up on tubing or IA for 30 minutes. If all is stable, then proceed with step 5 below. 5. Open blind rams. Back out tubing hangar hold down studs on tubing head flange. Screw joint of 4 1 /" IBTM tubing with 4 1 /" IBTM box x NSCT pin crossover into top of tubing hanger or have Baker 4 %" spear on hand to run on 4" HT -40 DP if need be to spear the 4 1 /2" tubing in order to pull hanger /pack -off assembly to floor.. Have FMC representative on site when pulling hangar. NOTE: Have stabbing valve made up on crossover for 4 %/2" NSCT tubing during lay down of tubing. 6. Pull up to shear tubing from RCT cut made at 11,527'prior to 7ES MIRU. The RCT cut should have completely severed the tubing so no shearing may be seen. POOH laying down all 4 %/2" NSCT tubing string and associated jewelry. NOTE: Have 4%" NSCT thread protectors on hand to put on tubing during lay down. Store all •%" NSCT tubing on Badami airport pad. Be sure the new FMC tubing head spool & all associated items that will be required in step 9 below are on location along with a 11" 5K x 13 -5/8" 5K DSA. 7. Change BOPE rams to 4" if not covered by VBR & test. Install wellhead wear sleeve. 4 8. RIH with Baker 7" STORM PACKER on 4" HT -40 DP. Set storm packer @ approx 4000'. Release from packer. Pressure test 7 "casing & storm packer to 1000 psi. POOH w/ DP. 9. PU 13 5/8" BOP stack. Remove 11" 10K x 13 5/8" 5K DSA. ND existing 11" 5K bottom x 11" 10K top tubing head. NU new FMC 11" 5K bottom x 11" 5K top tubing head needed for ESP completion. Pressure test new tubing head as required. Using 11" 5K x 13 5/8" 5K DSA, NU 13 5/8" BOP & pressure test per AOGCC regulations. 10. RIH w /DP to retrieve STORM PACKER. Latch packer & POH laying down DP. Install 2 7/8" b�L rams if not covered by VBR & test same. Retrieve wellhead wear sleeve. FOLLOW ATTACHED BAKER HUGHES ESP 2 -7/8" COMPLETION STRING RUNNING & LANDING PROCEDURE 11. Run new 2 7/8" 6.5# 8rd EUE L -80 tubing with Centrilift ESP with power cable, XN & X nipples, heat tape, GLMs & SCSSSV completion string and land with bottom of ESP @ approx. 11500' NOTE: Do not over dope tubing. Optimum torque for 2 -7/8" tubing is 2300 ft lbs. Be sure there are spacer 2 -7/8" tubing pups on location to use as needed. NOTE: Make sure the one ( 1 ) GLM has been pressure tested with 1.0" E DGLV w /BK Series latch in place. LGLV to be installed as directed after Nabors 9ES moves off. Page 7 of 8 SAVANT ALASKA • • 12. Install BPV. Close SSSV. ND BOPE. NU Tree & test same. 13. Release Nabors 7ES, RDMO 14. Release well to Badami Production Facilities. They will install flow line, SCSSSV surface controller panel tie -in and well house prior to putting the well on ESP production. NOTE: Be sure all Savant Alaska LLC owned or rented crossover subs & tubing pups are removed from rig & put in Savant inventory or returned to applicable vendors before rig demobilizes back to Deadhorse. lo/(10 Submit AOGCC Forms 4within 7 days of rig release. Page 8 of 8 • • B1 -16 ESP COMPLETION STRING RUNNING /LANDING PROCEDURE Pre -Job Checklist Tally all pipe as it is loaded onto the pipe rack. Remove all thread protectors and visually inspect the threads for damage. Clean only if needed and visually inspect the threads. Drift tubing with Teflon drift. If the tubing fails the drift test, have the ends of the drift checked for OD. Normal wear on the drifts can enlarge the ends so that they will not pass through the tubing. Check and strap all space out pups. Drift all pups. Check all tubing, crossover, combination couplings and pup joint for proper threads. Drift tubing hanger and pup joint. Strap all accessories. Record length of all pup joints, GLM's, SSSV and landing nipples and all other completion jewelry on the Completion Detail form. Purge SSSV control line with hydraulic fluid and test to 5000 PSI. Prior to running completion a) Pull wellhead wear sleeve protector b) Be sure XMAS Tree, tubing hanger & hanger pack -off are on location & tubing hanger has 2 7/8" 8rd EUE pin down. The new 2 7/8" TRMAXX -5e SCSSSV requires only one (1) control line port. c) Be sure to have connection needed to get pump line onto tubing wing valve on tree & IA valve on wellhead d) While tubing is in pipe shed, remove tubing thread protectors. e) Have complete tailpipe assembly with 10' pup jt. on top all made up & in pipe shed ready to be RIH f) Be sure all Cannon Control Line Clamps needed are on location. g) Be sure that2 7/8" XN nipple has RHC plug installed to be run in place in hole. h) Be sure to have TIW stabbing valve crossed over to 2 7/8" 8rd EUE on rig floor Running Procedure for Centrilift ESP Completion String NOTE: See attached Completion Tubing String Detailed running order 1. The one (1) GLM is to be run (all with 1" DGLV in place) as near to the following TVD's as possible: 150' TVD (150'MD). This GLM is for recombining IA gas back into tubing near surface. • • B1 -16 ESP COMPLETION STRING RUNNING /LANDING PROCEDURE 2. Nipples, GLM & SSSV are all to come to location pressure tested with properly torqued pups Jts. installed top & bottom. 3. Fill Tubing with NACL every 20 joints while RIH if needed. NOTE: The well will be full of 9.4# NACL water when completion string is run. The tubing should fill OK as RIH. 4. SEE ATTACHED BAKER CENTRILIFT RUNNING & LANDING PROCEDURE 5. PU & RIH with 2 7/8" tubing completion string as per attached detailed running order. Limit RIH speed to NO MORE than 60 ft/min. Optimum make up torque is 2300 ft. lbs. After installing SSSV & 1/4" SS control line test SSSV for proper operation. Maintain 5500 psi on SSSV control line while RIH. Secure ESP power cable, heat tape & SSSV control line to tubing using the Cannon Control Line clamps. Place clamps at mid -joint & across coupling on every joint to surface & as recommended by Baker Centrilift. 6. Pick up the required amount of tubing and /or pup joints with tubing hanger /pack -off assembly in order to space out as needed. The top thread on tubing hangar is 2 7/8" 8rd EUE. MU a landing joint of 2 7/8" 8rd EUE tubing onto tubing hanger. 7. Be sure SSSV control line, ESP power cable & heat tape are all thru hangar & tested as required. Land tubing hanger. Run in lock down screws on tubing head flange for tubing hanger. Pressure test tubing hangar pack -off. 8. Hook up pump lines & chart recorder to both tubing & IA. Using diesel, pressure test lines to 1500 psi. 9. Be sure IA & tubing is open. Using reverse circulation & diesel, pump 85 bbls down IA using max. pump rate of one (1) BPM then allow IA to "U" tube diesel back into tubing until IA & tubing are equalized. NOTE: Do not exceed 1000 psi pump pressure while reversing in diesel. Dispose of NACL water. 10. Back out landing jt. & lay down. 11. Install BPV. Close SSSV. ND BOPE. 12. Hook up & test SSSV control line, ESP power cable & heat tape on wellhead as needed. Pressure test control line to 6000 psi. Ensure proper operation of SSSV, ESP power cable & heat tape. NU XMAS Tree using the FMC provided 2 1/16" 5K x 4 1/16" 5K DSA & test tree with diesel to 3000 psi. Retrieve BPV. Open SSSV. NOTE: Be sure Tree tubing wing valve is oriented as other Badami wells for flow line hook up. 13. Release Nabors 7ES for rig move. 14. After Nabors 7ES is off well, have FMC pull BPV. • • B1 -16 ESP COMPLETION STRING RUNNING /LANDING PROCEDURE 15. Have Baker Centrilift hook up ESP power cable & heat tape as & test as required. 16. Close SSSV. 17. Release well to Badami CPF. Have CPF personnel re- install & test both flow line & GL line along with SCSSSV control panel, SSV controls. Install well house & floor grating. 18. Place well on ESP lift for production per Baker Centrilift recommendations. • • 0 HALLIBURTQN 1 MI Pressure Gauge Report a Savant Alaska, LLC B1 -16 Badami Pressure Build Up November 10, 2011 to November 10, 2011 BIB •1. SAVANT 1 .i1 1 UT. 1 y . This report is based on sound engineering practices, but because of variable well conditions and other information which must be relied upon, Halliburton makes no warranty, express or implied, as to the accuracy of the data or of any calculations c opinions expressed herein. Halliburton shall not be liable for any loss or damage whether due to negligence or otherwise arising out of or in connection with such date calculations or opinions. • • H A L L I B U R T O N CUSTOMER WELL NO. Savant Alaska, LLC B1 -16 CUSTOMER REP PHONE NO. Zane Henning 868 -1258 x106 Bottom Hole Pressure Survey Results FIELD SALES ORDER Badami 9040057 JOB TYPE NETWORK CODE Static BHP Survey AK076519 WELL API PAD/WELL ENGINEER HALLIBURTON REP(S) Not Provided Eric Opstad Gary Rainey R. Curtis Duncan LOG START DATE LOG END DATE November 10, 2011 November 10, 2011 Delta Upper Gauge Lower Gauge Date Time Time MD SS 75190 Sapphire 4131 Sapphire (hrs) Press. (psia) Temp. Press. (psia) Temp. 11/10/2011 12:43:40 3.48 Surface - 572.15 21.60° F 574.55 25.64° F 11/10/2011 13:03:47 3.81 2,000' MD - 1301.87 30.89° F 1300.98 30.98° F 11/10/2011 13:24:31 4.16 4,000' MD - 1930.96 48.62° F 1930.46 45.36° F 11/10/2011 13:44:48 4.50 6,000' MD - 2452.23 71.30° F 2455.41 67.36° F 11/10/2011 14:03:39 4.81 8,000' MD - 2952.10 99.72° F 2955.52 94.49° F 11/10/2011 14:26:51 5.20 10,000' MD - 3458.68 130.05° F 3460.95 125.60° F 11/10/2011 15:13:43 5.98 12,497' MD - 4257.38 177.09° F 4260.08 176.86° F 11/10/2011 15:35:49 6.35 10,000' MD - 3456.00 131.55° F 3459.69 133.21° F 11/10/2011 15:51:46 6.61 8,000' MD - 2949.74 101.59° F 2954.56 103.51° F 11/10/2011 16:07:46 6.88 6,000' MD - 2451.13 72.82° F 2457.11 74.59° F 11/10/2011 16:23:48 7.15 4,000' MD - 1932.97 50.74° F 1940.75 52.46° F 11/10/2011 16:40:47 7.43 2,000' MD - 1309.29 32.74° F 1314.16 34.20° F 11/10/2011 17:05:02 7.83 Surface - 582.51 21.10° F 585.25 25.76° F Comments: Sub -Sea was not provided Unusual Events: • • H A L L I B U R T O N CUSTOMER WELL NO. Savant Alaska, LLC B1 - CUSTOMER REP PHONE NO. Zane Henning 868 -1258 x106 Sequence of Operations FIELD SALES ORDER Badami 9040057 JOB TYPE NETWORK CODE Static BHP Survey AK076519 WELL API PAD/WELL ENGINEER Not Provided Eric Opstad HALLIBURTON REP(S) LOG START DATE LOG END DATE Gary Rainey R. Curtis Duncan November 10, 2011 November 10, 2011 Date Time Description 11/10/2011 SBHP will be performed this morning. 11/10/2011 9:00:00 Walk S/L operator through the gauge process. 17:00:00 Informed Gauges are coming OOH. 17:25:00 Walk Operator through the DL process & export. Will ship gauges on next available flight. 21:00:00 Travel to 70North hanger & pick up gauges. 21:30:00 DL gauges & process Data per Vince. 23:30:00 Finished, send Data & Report to Erik & Zane. • 0 HAL..1-113URTON CUSTOMER CUSTOMER REP Zane Henning PHONE NO. NETWORK CODE Savant Alaska, LLC 868-1258 x106 AK076519 HALLIBURTON RENS) Gary Rainey JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1-16 9040057 R. Curtis Duncan Pressure Plots Savant Alaska Inc. B1-16 SBHPS (75190) 11-10-2011 Pressure Temperature -7:-180 , = I _ =170 40 __ - 00 = 160 / \ = =160 3500 -/ - v_., - -. - _ =140 - --inn -I _ 120 w r _ r.; —110 co ... _ = _ to - 1 -90 c \-- ..." \\.......„.: _ r __/ _ = 30 500- lif ...V2o - —10 _ 0 ll. mi 1 ..., m. . ., 111. ,111 11 - 3.5 1.0 1 .5 5.0 6.5 6.0 6.5 7.0 7.5 8.0 Time (hr I 1 • • HALL 1 B U R TO N CUSTOMER CUSTOMER REP PHONE NO. NETWORK CODE HALLIBURTON REPIS) Savant Alaska, LLC Zane Henning 868 -1258 x106 AKO76519 Gary Rainey JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1 -16 9040057 R. Curtis Duncan Pressure Plots Savant Alaska Inc. B1 -16 SIBEiPS (4131) 11 -10 -2011 Pressure Temperature • 180 =1 /U 4000 ' =160 =150 3500 =140 - _ =130 20 3000 /I:: =13 cn ' =110 °'2500- _ m = i = 100 It 2000 _ = 90 "c. 1500 =70 =60 ,000 - =50 _ 500- / N -30 - 20 0 !I 1 1 1 I l I l t I I , t l l i I l 1 ■ I I I I 1 1 1 I .-.10 3 .5 4.0 X1.5 5.0 5.5 6.0 6.5 7.0 7.5 8!0 Time (hr} • • CUSTOMER CUSTOMER REP PHONE NO. NETWORK CODE HALLIBURTON REPS) HALL 1 B U RTO PJ Savant Alaska, LLC Zane Henning 868 -1258 x106 AK076519 Gary Rainey JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1 -16 9040057 R. Curtis Duncan WELL API PAD/WELL ENGINEER LOG START DATE LOG END DATE Not Provided Eric Opstad November 10, 2011 November 10, 2011 Equipment Specifications DynaMem Pro Specifications Gauge Serial Number 75190 Calibration Date April 27, 2011 Pressure Rating 15,000 psi Temperature Rating 170 °C / 338 °F Data Points Available 1,000,000 Sensor Type Sapphire Pressure Accuracy 0.025% Resolution 0.0003% Temperature Accuracy 0.20° F Pressure Drift < 3 psi / year Housing Material Inconel 718 O.D. 1.25" 1 Length 17.00" • DynaMem Pro SPG Specifications Gauge Serial Number 4131 Calibration Date January 21, 2011 Pressure Rating 15,000 psi Temperature Rating 170 °C / 338 °F Data Points Available 1,000,000 Sensor Type Sapphire Pressure Accuracy 0.022% Resolution 0.0003% Temperature Accuracy 0.20° F Pressure Drift < 3 psi / year Housing Material Inconel 718 O.D. 1.00" i Length 19.00" • • g a.<,_ ,i -r- prb t 26 D6vo Regg, James B (DOA) From: Vince Sarro [Vince.Sarro @Savantalaska.com] Z Sent: Monday, February 13, 2012 9:10 AM -\ eqq Y12— To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA sponsored) Cc: DrillingandWells @Savantalaska.com Subject: Results of B1 -16 MIT -IA conducted on 2/11/2012 Attachments: 2 -11 -2012 B1 -16 MIT -IA AOGCC TEST.pdf Mr. Regg, Here are the results of the MIT -IA done on 2/11/2012 for Well B1 -16 at Badami. Ma .0 p ,Atcet - Thanks, Vince t jowl) FEB i b Z ii i 4. dr ;i Vince Sarro Drilling & Wells Email: Vince.SarroCWSavantA /aska.com Contact # : 907 - 947 -2135 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical integrity Test Submit to: jimseociabalaska.00v ; doa .aogcc.prudhoe.bavOalaska.00v; phoebe.brookstbalaska.00v; tom.maunder(talaska.gov OPERATOR: Savant Alaska LLC FIELD 1 UNIT /PAD: Badami DATE: 02/11/12 OPERATOR REP: Vince Sarro,Savant Alaska, Drilling &Wells AOGCC REP: John Crisp/Waived Witness 2/10 /2012 :1_C.e1 c oe g Packer Depth Pretest Initial 15 Min. _ 30 Min. 45 Min. 60 Min. � Wet B1 -16 Type Inj. N TVD 8,908' Tubing 100psi 100psi 100psi 100psi 100psi 100psi Interval 0 P.T.D. 198 -80 Type test P _ Test psi 2500 Casing 250psi 2500psi ✓ 2450psi 2450psi 2450psi 2450psi r P/F P Notes: MIT -IA before Workover on the Well. ., OA 450psi 450psi 450psi 450psi 450psi 450psi -' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi , Casing P/F Notes: OA Wet Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) Copy of AOGGC MIT Form.xls Well Compliance Report File on Left side of folder 198-080-0 BADAMI UNIT MD 13372 TVD 10633 Completion Date: Microfilm Roll / - Roll 2 / Bl-16 50- 029-22880-00 BP EXPLORATION (ALASK A ~ l~Tf~ 8/9/98 Completed Status: 1-OIL Current: Name Interval D 8462 L~5~PX CCL/GR/SBT CH D 8770 ~ SPERRY MPT/GR/EWR4 OH Sent Received 6/23/98 6/25/98 10/7/98 10/8/98 T/C/D D 8847 1 ~.WA MAC L CDL/CN/GR ~'~AL 11886-13268 L GR/CCL C..~' L G~CCL ~ OH 5390-13372 -~,:~.~[q ~- ~ ~ OH 4609-10633 /~ OH 13040-13200 /f' ~-~d CH 11750-12900 q 0~' q ~ CH L HDVGR ~~ 11744-13375 ~/~/~ ~ OH L HDVGR-TVD. 11744-13375 '" OH L ~VG~SST~ ~F~ 11744-13375 OH L ~C ~ BL(C)11900-13250 ¢[~[~ ~. O 5 L ~C/GR ~ 11866-13375 * ¢['~3~ OH 5 CH 5 L SBT ~ 10470-11926 }~t ~ CH 5 L SBT ~ 11380-13232 5 ~)'7 ~ CH 5 L STATP~SSRVY '~ 12950-13130 3- ~3 ~ v',.}, ~ fi CH R SRVY ~T ~PE~Y 3385.37-13372. OH 1/13/99 1/14/99 6/23/98 7/2/98 10/7/98 10/8/98 10/7/98 10/8/98 10/5/98 10/6/98 10/5/98 10/6/98 6/23/98 7/2/98 6/23/98 7/2/98 6/23/98 7/2/98 7/28/98 8/3/98 6/23/98 7/2/98 8/31/98 9/2/98 6/23/98 7/2/98 8/31/98 9/2/98 10/5/98 10/6/98. 7/22/98 7/23/98 R SRVY RPT ,-S-FERRY 542-4839. PB1 OH T 8961 c~l~' SCHLUM 1MP-GR/RES OH . .yW ll · Are Dry Ditch Samples Required? yes Was the well cored? yes ~_.~_- Analysis Description Recei~'¢d? - y~s iio Comments: 7/22/98 7/23/98 1/18/99 1/21/99 And Rec~ Samph~$e~... , ,'. Tuesday, August 01, 2000 Page 1 of 1 BP EXPLORATION, Alaska Date: 1-13-98 Trans~ 90138 BADAMI OPEN HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 ISw Name IRec Type Rec Date ICompany Code IComments Please sign and return one copy of this tr,,aqsmittal to: Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC - 1 disk Howard Oakland PETROFINA 1 disk Mike Engle DNR - 1 disk Tim Ryherd JAN ,--r ,,, ;,~ ,-Naska 0ii & Gas Cons. OommissiOl3. .&~ch, ora§e Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA . ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REVISED 10/27/98 1. Status of Well Classification of Service Well [~Oil [~Gas I~ Suspended ~]Abandoned I~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-80 398-130 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22880 ~':,%... ~ . ' '- · 9. Unit or Lease Name 4. Location of well at surface ~" 3855' NSL, 107' WEL, SEC. 8, T9N, R20E, UM~~~~ .~~~ ~~ ], Badami Unit At top of productive interval , [..~I~ 10. Well Number 5221 'NSL, 1294' WEL, SEC. 32, T10N, R20E, UM~~~~' ~.: ~7~.. i B1-16 At total depth ~~~ 11. Field and Pool 27' NSL, 1325' WEL, SEC. 32, T10N, R20E, UM Badami :5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 54.3'~ ADL 367006 12. Date Spudded5/3/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re ~ 16' NO' Of cOmpletiOns6/6/98 8/9/98 N/A MSLI One 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D)~19. Directional Su~ey ~20. Depth where SSSV set ~21. Thickness of Permafrost 13372 10633 FT 13286 10549 FT~ ~ Yes ~ No~ (Nipple) 2208' MD ~ 1900' (Approx.) 22. Type Electric or Other Logs Run Gyro, HWDP/MWD, DIUBHC/GR, Z-Densilog-GR, CDL 23. CASING, LINER AND CEMENTING RECORD CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM SIZE CEMENTING RECORD A~¢~~ 20" 91.1~ H-40 37' 110' 24" 260 sx Arctic Set (Approx.) ~-; ~, ~" '~,.~ ~" ~ ¥:~ ~:~ ~,~-~-'~ 9-5/8" 40ff L-80 35' 5377' 12-1/4" 2924 sx PF 'E', 385 sx Class 'G' 7" 29~ USS-95 33' 11928' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6fl L-80 11752" 13372 6" 205 sx Class 'G' 24. Pedorations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER S~ (MD) 3-3/8" gun diameter, 6 spf 4-1/2", 12.6ff, L-80 11586' 11557' MD TVD MD ~D 13130' - 13150' 10398' - 10418' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 13150' - 13170' 10418' - 10437' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 13170' - 13190' 10437'- 10456' Freeze protect with 140 bbls diesel U K I ! L Date First Production I Method of Operation (Flowing, gas lift, etc.) September 28, 1998I Flowin~ Date of Test Hours Tested ~RODUCTION FOR O~L-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OIL ~T[O TEST PERIOD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-~CF WATER-BBL O~L GRAV~-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers" 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Base Badami Sands J2 12835' 10117' Top Badami Sands A5 13025' 10298' Base Badami Sands A5 13184' 10450' 31. List of Attachments Attached to well completion report filed onJj~7/22/98. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~ ~,~-~ Mike E. Miller Title Badami Drilling Team Leader B1-16 98-80 398-130 Prepared By Name/Number: Carol W/they, 564-4114 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 B1-16 '~- DESCRiPTiON OF WORK COMPLETED Initial Perforation 08/09/98 SUMMARY The following initial interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 13130'- 13150' MD 13150'- 13170' MD 13170'- 13190' MD ADDPERF 09/15/98 SUMMARY The following additional interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 13154' - 13174' MD Performance Enquiry Report Operator BP Exploration Date 00:33, 08 Jul 98 Page The analysis is from - 02:45, 01 Jun 98 - to - 14:00, 04 Jun 98 Programs in Result Table: B 1-16 Well Bl-16 Bl-16 Bl-16 Bl-16 TyDe Event Event Event Event Time From Time To Duration Description E.M.W.(equivalent mud weight) Hole Size MDR 02:45, 01 Jun 98 02:45, 01 Jun 98 0 hr 0 min Obtained leak off 12.4 6 03:30, 01 Jun 98 03:30, 01 Jun 98 0 hr 0 min Obtained leak off 11.9 6 15:00, 03 Jun 98 15:00, 03 Jun 98 0 hr 0 min Obtained required level of integrity 13.2 6 14:00, 04 Jun 98 14:00, 04 Jun 98 0 hr 0 min Obtained required level of integrity 13.3 6 Progress Report Facility Badami CPF Well Bl-16 Rig Nabors 28E Page 1 Date 07 July 98 Date/Time 02 May 98 00:00-06:00 06:00-18:00 18:00-00:00 03 May 98 00:00-03:30 03:30-06:00 06:00-13:30 13:30-16:00 16:00-16:30 16:30-17:30 17:30-18:15 18:15-19:00 19:00-21:00 21:00-23:00 23:00-00:30 04 May 98 00:30-01:00 01:00-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:00 21:00-22:00 22:00-23:00 23:00-00:00 05 May 98 00:00-01:00 01:00-01:30 01:30-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-16:00 16:00-16:30 16:30-06:00 06 May 98 06:00-06:30 06:30-07:30 Duration 6 hr 12hr 6 hr 3-1/2 hr 2-1/2 hr 7-1/2 hr 2-1/2 hr 1/2 hr 1 hr 3/4 hr 3/4 hr 2hr 2hr 1-1/2 hr 1/2 hr 5hr 1-1/2 hr lhr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 1 hr lhr 1/2 hr 1 hr 1 hr 1 hr lhr 1/2 hr 1 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 13-1/2 hr 1/2 hr 1 hr Activity Rig moved 50.00 % Rig moved 100.00 % Rigged up Additional services Rigged up Additional services Fill pits with Water Fill pits with Water based mud Made up BHA no. 1 Held safety meeting Drilled to 221.0 ft Laid down 90.0 ft of 5in OD drill pipe Made up BHA no. 1 Drilled to 290.0 ft Took Gyro survey at 290.0 ft Drilled to 380.0 ft Took Gyro survey at 380.0 ft Drilled to 475.0 ft Drilled to 528.0 ft Took Gyro survey at 449.0 ft Drilled to 541.0 ft Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 541.0 ft Drilled to 568.0 ft Pulled out of hole to 200.0 ft Pulled BHA Rig waited · Equipment Ran Drillpipe in stands to 541.0 ft Worked toolstring at 541.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 568.0 ft Worked toolstring at 568.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe to 568.0 ft (5in OD) Pulled Drillpipe in stands to 0.0 ft Laid down 90.0 ft of Drillpipe Made up BHA no. 3 R.I.H. to 568.0 ft Drilled to 575.0 ft Circulated at 575.0 ft Pulled out of hole to 100.0 ft Pulled BHA Ran Drillpipe in stands to 575.0 ft Conducted electric cable operations Circulated at 575.0 ft Washed to 585.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 3 R.I.H. to 585.0 ft Drilled to 650.0 ft Serviced Fluid system Drilled to 1375.0 ft Drilled to 1367.0 ft Circulated at 1367.0 ft Progress Report Facility Badami CPF Well B 1-16 Rig Nabors 28E Page 2 Date 07 July 98 Date/Time 07:30-08:30 08:30-09:00 09:00-09:15 09:15-10:00 10:00-06:00 07 May 98 06:00-07:00 07:00-08:00 08:00-10:30 10:30-11:00 11:00-14:00 14:00-14:30 14:30-16:30 16:30-06:00 08 May 98 06:00-19:30 19:30-00:30 09 May 98 00:30-01:30 01:30-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-16:45 16:45-17:30 17:30-22:00 22:00-06:00 10 May 98 06:00-07:30 07:30-08:00 08:00-12:00 12:00-12:30 12:30-21:30 21:30-00:30 11 May 98 00:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-09:30 09:30-12:00 12:00-14:00 14:00-17:30 17:30-20:00 20:00-20:30 20:30-23:00 23:00-02:00 12 May 98 02:00-03:30 03:30-05:00 05:00-06:00 06:00-07:00 07:00-08:30 08:30-09:15 09:15-10:30 10:30-12:30 12:30-13:00 13:00-15:00 15:00-17:30 Duration 1 hr 1/2 hr 1/4 hr 3/4 hr 20 hr lhr 1 hr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 2hr 13-1/2 hr 13-1/2 hr 5hr lhr 2hr 1/2 hr 1/2 hr 1-1/2 hr 2 hr 8-3/4 hr 3/4 hr 4-1/2 hr 8hr 1-1/2 hr 1/2 hr 4hr 1/2 hr 9 hr 3hr 3 hr 1/2 hr 2hr 1/2 hr 3hr 2-1/2 hr 2hr 3-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 3 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1-1/2 hr 3/4 hr 1-1/4 hr 2hr 1/2 hr 2hr 2-1/2 hr Activity Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 1367.0 ft Drilled to 2375.0 ft Drilled to 2424.0 ft Circulated at 2424.0 ft Pulled out of hole to 202.0 ft Pulled BHA Serviced Draw works Made up BHA no. 5 R.I.H. to 2424.0 ft Drilled to 3150.0 ft Drilled to 4038.0 ft Pulled out of hole to 214.0 ft Pulled BHA R.I.H. to 2777.0 ft Washed to 2777.0 ft R.I.H. to 3455.0 ft Washed to 3655.0 ft Washed to 4038.0 ft Drilled to 4536.0 ft Serviced Mud shakers Drilled to 4839.0 ft Worked stuck pipe at 4839.0 ft Jarred stuck pipe at 4839.0 ft Tested Block line Jarred stuck pipe at 4839.0 ft Held safety meeting Removed Kelly Circulated at 4839.0 ft Conducted electric cable operations Held safety meeting R.I.H. to 4733.0 ft Conducted electric cable operations Serviced Drillpipe Conducted electric cable operations Circulated at 4839.0 ft Conducted electric cable operations Conducted electric cable operations Circulated at 4839.0 ft Conducted electric cable operations Pulled Drillpipe in stands to 0.0 ft Serviced Block line Made up BHA no. 7 Singled in drill pipe to 1108.0 ft Singled in drill pipe to 1934.0 ft Serviced HP air supply Singled in drill pipe to 3005.0 ft R.I.H. to 4594.0 ft Circulated at 4594.0 ft Fished at 4594.0 ft Jarred stuck pipe at 4594.0 ft Fished at 4594.0 ft Facility Date/Time 13 May 98 14 May 98 15 May 98 16 May 98 17 May 98 18 May 98 19 May 98 Badami CPF 17:30-21:15 21:15-23:30 23:30-03:00 03:00-06:00 06:00-07:00 07:00-08:30 08:30-08:45 08:45-09:30 09:30-21:00 21:00-22:30 22:30-00:00 00:00-01:30 01:30-04:00 04:00-06:00 06:00-06:30 06:30-13:30 13:30-16:00 16:00-19:30 19:30-21:00 21:00-06:00 06:00-23:30 23:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-11:30 11:30-13:30 13:30-14:00 14:00-15:30 15:30-16:00 16:00-17:00 17:00-06:00 06:00-20:30 20:30-00:00 00:00-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-08:30 08:30-13:00 13:00-18:30 18:30-20:30 20:30-21:30 21:30-23:00 23:00-23:30 23:30-06:00 06:00-07:00 07:00-11:00 11:00-12:30 12:30-13:15 13:15-18:00 Duration 3-3/4 hr 2-1/4 hr 3-1/2 hr 3hr 1 hr 1-1/2 hr 1/4 hr 3/4 hr 11-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2 hr 1/2hr 7hr 2-1/2 hr 3-1/2 hr 1-1/2 hr 9hr 17-1/2 hr 2-1/2 hr 2hr lhr 1 hr 2hr lhr 1-1/2 hr 1 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr lhr 13hr 14-1/2 hr 3-1/2 hr 2hr lhr 1-1/2 hr 1-1/2 hr 2-1/2 hr 4-1/2 hr 5-1/2 hr 2 hr 1 hr 1-1/2 hr 1/2 hr 6-1/2 hr 1 hr 4hr 1-1/2 hr 3/4 hr 4-3/4 hr Progress Report Well Bl-16 Rig Nabors 28E Activity Conducted electric cable operations Pulled Drillpipe in stands to 4413.0 ft Ran Drillpipe in stands to 4390.0 ft Circulated at 4391.0 ft Circulated at 4391.0 ft Mixed and pumped slurry - 144.000 bbl Displaced slurry - 57.000 bbl Pulled Drillpipe in stands to 3002.0 ft Circulated at 3002.0 ft Pulled Drillpipe in stands to 3002.0 ft Ran Drillpipe in stands to 1302.0 ft Laid down 1302.0 ft of Drillpipe Made up BHA no. 8 R.I.H. to 1330.0 ft R.I.H. to 1600.0 ft Washed to 3360.0 ft Circulated at 3360.0 ft Drilled to 3471.0 ft Serviced Mud pumps Drilled to 3558.0 ft Drilled to 4137.0 ft (cont...) Circulated at 4137.0 ft Pumped out of hole to 3735.0 ft Pumped out of hole to 3575.0 ft Pulled out of hole to 3100.0 ft Pulled out of hole to 659.0 ft Pulled BHA Serviced Draw works Made up BHA no. 9 R.I.H. to 3715.0 ft Reamed to 3715.0 ft Circulated at 3715.0 ft R.I.H. to 3900.0 ft Reamed to 4137.0 ft Drilled to 4700.0 ft Drilled to 5390.0 ft Circulated at 5390.0 ft Pulled out of hole to 2792.0 ft Circulated at 2792.0 ft Pulled out of hole to 695.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 5160.0 ft Circulated at 5390.0 ft Pulled out of hole to 129.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 9-5/8in (5200.0 ft OD) Ran Casing to 5376.0 ft (9-5/8in OD) (cont...) Circulated at 5376.0 ft Mixed and pumped slurry - 195.000 bbl Displaced slurry - 402.000 bbl Circulated at 5376.0 ft Page Date 3 07 July 98 Facility Date/Time 20 May 98 21 May 98 22 May 98 23 May 98 24 May 98 25 May 98 26 May 98 27 May 98 Badami CPF 18:00-21:00 21:00-21:30 21:30-02:00 02:00-06:00 06:00-06:15 06:15-15:30 15:30-19:30 19:30-02:00 02:00-06:00 06:00-08:30 08:30-09:30 09:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-23:00 23:00-23:30 23:30-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-03:00 03:00-06:00 06:00-00:30 00:30-01:00 01:00-03:00 03:00-03:30 03:30-05:30 05:30-06:00 06:00-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-06:00 06:00-20:30 20:30-22:00 22:00-23:00 23:00-00:00 00:00-06:00 06:00-00:30 00:30-01:00 01:00-02:00 02:00-02:30 02:30-06:00 06:00-01:00 01:00-01:45 01:45-02:30 Duration 3hr 1/2 hr 4-1/2 hr 4hr 1/4 hr 9-1/4 hr 4 hr 6-1/2 hr 4 hr 2-1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr lhr 1 hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 1 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr 3 hr 18-1/2 hr 1/2 hr 2hr 1/2 hr 2hr 1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 1 hr 1/2 hr 16hr 14-1/2 hr 1-1/2 hr lhr lhr 6hr 18-1/2 hr 1/2 hr 1 hr 1/2 hr 3-1/2 hr 19hr 3/4 hr 3/4 hr Progress Report Well Bl-16 Rig Nabors 28E Activity Mixed and pumped slurry - 1017.000 bbl Displaced slurry - 166.000 bbl Cleared Flowline Removed Divertor Rigged down Divertor Rigged up BOP stack Ran Drillpipe in stands to 2700.0 ft Rigged up Kill manifold Tested BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 11 Functioned downhole tools at 647.0 ft R.I.H. to 2183.0 ft Rigged up Mud shakers Drilled cement to 2185.0 ft R.I.H. to 5220.0 ft Circulated at 5220.0 ft Drilled to 5285.0 ft Circulated at 5285.0 ft Tested Casing - Via annulus and string Drilled cement to 5390.0 ft Drilled to 5410.0 ft Circulated at 5410.0 ft Opened hole to 5410.0 ft (8-1/2in) Drilled to 5440.0 ft Circulated at 5440.0 ft Circulated at 5440.0 ft Drilled to 5640.0 ft Drilled to 6850.0 ft Circulated at 6850.0 ft Drilled to 7010.0 ft Circulated at 7010.0 ft Drilled to 7127.0 ft Circulated at 7127.0 ft Drilled to 7360.0 ft Circulated at 7360.0 ft Pulled out of hole to 5315.0 ft Serviced Block line R.I.H. to 7360.0 ft Drilled to 8317.0 ft Drilled to 9173.0 ft Circulated at 9173.0 ft Pulled out of hole to 7220.0 ft R.I.H. to 9173.0 ft Drilled to 9465.0 ft Drilled to 10606.0 ft Circulated at 10606.0 ft Pulled out of hole to 9052.0 ft R.I.H. to 10606.0 ft Drilled to 10800.0 ft Drilled to 11816.0 ft Circulated at 11816.0 ft Drilled to 11848.0 ft Page Date 4 07 July 98 Facility Date/Time 28 May 98 29 May 98 30 May 98 31 May 98 Badami CPF Progress Report Well B 1-16 Page 5 Rig Nabors 28E Date 07 July 98 Duration Activity 02:30-03:15 03:15-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-10:30 10:30-13:30 13:30-16:30 16:30-18:30 18:30-20:00 20:00-01:00 01:00-02:00 02:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-07:15 07:15-13:30 13:30-14:00 14:00-20:30 20:30-22:30 22:30-00:00 00:00-01:00 01:00-02:00 02:00-04:00 04:00-05:30 05:30-06:00 06:00-10:30 10:30-11:00 11:00-15:00 15:00-17:30 17:30-02:30 02:30-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-09:00 09:00-12:00 12:00-19:30 19:30-22:00 22:00-22:45 22:45-00:15 00:15-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-09:00 09:00-11:45 11:45-13:30 13:30-19:00 19:00-20:00 20:00-23:30 23:30-23:45 23:45-00:15 3/4 hr 1-1/4 hr 1 hr 1/2 hr 1-1/2 hr 3hr 3hr 3 hr 2hr 1-1/2 hr 5hr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 3/4 hr 6-1/4 hr 1/2 hr 6-1/2 hr 2hr 1-1/2 hr 1 hr lhr 2hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 4hr 2-1/2 hr 9 hr 2-1/2 hr 1/4 hr 1/4 hr 1/2 hr 3hr 3hr 7-1/2 hr 2-1/2 hr 3/4 hr 1-1/2 hr 3/4 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 2-3/4 hr 1-3/4 hr 5-1/2 hr lhr 3-1/2 hr 1/4hr 1/2 hr Circulated at 11848.0 ft Drilled to 11912.0 ft Circulated at 11912.0 ft Drilled to 11944.0 ft Circulated at 11944.0 ft Pulled out of hole to 5300.0 ft R.I.H. to 11944.0 ft Circulated at 11944.0 ft Laid down 4060.0 ft of 5in OD drill pipe Serviced Drillstring handling equipment Laid down 2584.0 ft of 5in OD drill pipe Serviced Block line Laid down 1937.0 ft of 5in OD drill pipe Pulled BHA Serviced Top ram Serviced Top ram (cont...) Held safety meeting Ran Casing to 5384.0 ft (7in OD) Circulated at 5384.0 ft Ran Casing to 11928.0 ft (7in OD) Circulated at 11928.0 ft Mixed and pumped slurry - 41.000 bbl Rigged down Casing handling equipment Installed Seal assembly Installed BOP stack Installed Kelly Tested BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 12 Singled in drill pipe to 6750.0 ft Singled in drill pipe to 11945.0 ft Circulated at 11845.0 ft Rigged down Kelly Held safety meeting Tested Casing Tested Casing Functioned Casing hanger Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 1054.0 ft Tested Casing - Via annulus and string Ran Drillpipe in stands to 5056.0 ft Tested Casing - Via annulus and string Ran Drillpipe in stands to 11766.0 ft Tested Casing Tested Casing - Via annulus and string Injectivity test - 20.000 bbl injected at 1480.0 psi Functioned Retrievable packer Tested Casing Pulled out of hole to 0.0 ft Made up BHA no. 13 R.I.H. to 11844.0 ft Drilled installed equipment - Float collar Washed to 11927.0 ft Facility Date/Time 01 Jun 98 02 Jun 98 03 Jun 98 04 Jun 98 Progress Report Badami CPF Well B 1-16 Page 6 Rig Nabors 28E Date 07 July 98 00:15-00:30 00:30-00:45 00:45-01:45 01:45-02:45 02:45-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-09:30 09:30-10:00 10:00-12:00 12:00-16:30 16:30-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-03:00 03:00-03:10 03:10-03:45 03:45-04:45 04:45-05:30 05:30-05:45 05:45-06:00 06:00-06:30 06:30-07:30 07:30-13:00 13:00-14:00 14:00-18:00 18:00-21:00 21:00-00:00 00:00-06:00 06:00-12:00 12:00-12:15 12:15-13:00 13:00-15:00 15:00-15:30 15:30-18:00 18:00-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-09:45 09:45-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-14:30 14:30-17:00 Duration 1/4 hr 1/4 hr lhr 1 hr 3/4 hr 2-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2 hr 4-1/2 hr 6hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 0hr 1/2 hr 1 hr 3/4 hr 1/4 hr 1/4 hr 1/2 hr lhr 5-1/2 hr 1 hr 4hr 3 hr 3hr 6hr 6hr 1/4 hr 3/4 hr 2hr 1/2 hr 2-1/2 hr 2hr 4 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3-1/4 hr 1-1/4 hr 1 hr lhr lhr 1/2 hr 2-1/2 hr Activity Drilled installed equipment - Float shoe Washed to 11944.0 ft Circulated at 11944.0 ft Performed formation integrity test Performed formation integrity test Pulled out of hole to 6000.0 ft Pulled out of hole to 1000.0 ft Serviced Iron roughneck Pulled out of hole to 0.0 ft Held safety meeting Installed Lubricator Installed Instrument lines Conducted electric cable operations Ran Drillpipe to 11140.0 ft (4in OD) Set Cement retainer at 11140.0 ft with 0.0 psi Held safety meeting Tested Packer assembly Functioned Cement retainer Circulated at 11135.0 ft Held safety meeting Pumped Water spacers - volume 10.000 bbl Mixed and pumped slurry - 80.000 bbl Displaced slurry - 70.000 bbl Reverse circulated at 11135.0 ft Held 1700.0 psi pressure on 4.000 bbl squeezed cement Circulated at 11135.0 ft Held 1500.0 psi pressure on 0.900 bbl squeezed cement Circulated at 11135.0 ft Pulled Drillpipe in stands to 5.0 ft Made up BHA no. 14 R.I.H. to 11140.0 ft Circulated at 11140.0 ft Drilled installed equipment - Cement retainer Drilled cement to 11530.0 ft Drilled cement to 11930.0 ft Washed to 11940.0 ft Circulated at 11940.0 ft Performed formation integrity test Drilled to 11947.0 ft Circulated at 11947.0 ft Laid down 4617.0 ft of 4in OD drill pipe Pulled out of hole to 659.0 ft Pulled BHA Made up BHA no. 15 R.I.H. to 6748.0 ft Serviced Drillstring handling equipment Serviced Drillstring handling equipment Singled in drill pipe to 11406.0 ft R.I.H. to 11944.0 ft Drilled to 11967.0 ft Circulated at 11967.0 ft Performed formation integrity test Held safety meeting Drilled to 12037.0 ft Progress Report Facility Badami CPF Well Bl-16 Rig Nabors 28E Page 7 Date 07 July 98 Date/Time 05 Jun 98 06 Jun 98 07 Jun 98 08 Jun 98 09 Jun 98 17:00-18:15 18:15-18:45 18:45-21:30 21:30-04:30 04:30-05:30 05:30-06:00 06:00-06:00 06:00-21:00 21:00-22:15 22:15-00:30 00:30-01:45 01:45-03:00 03:00-06:00 06:00-08:30 08:30-15:30 15:30-17:30 17:30-00:00 00:00-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-15:15 15:15-15:45 15:45-18:15 18:15-19:45 19:45-20:30 20:30-22:30 22:30-05:00 05:00-05:30 05:30-05:45 05:45-06:00 06:00-06:30 06:30-08:00 08:00-08:15 08:15-09:30 09:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-15:30 15:30-16:00 16:00-17:45 17:45-18:30 18:30-18:45 18:45-21:45 21:45-22:15 22:15-23:30 23:30-00:00 Duration 1-1/4 hr 1/2 hr 2-3/4 hr 7 hr lhr 1/2 hr 24 hr 15hr 1-1/4 hr 2-1/4 hr 1-1/4 hr 1-1/4 hr 3hr 2-1/2 hr 7 hr 2hr 6-1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 1 hr 1/2 hr 1/2 hr 5hr 1/2 hr 1/2 hr 1/2 hr 1-3/4 hr 1/2 hr 2-1/2 hr 1-1/2 hr 3/4 hr 2 hr 6-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/4 hr 1-1/4 hr lhr 1/2 hr 1 hr 1/2 hr 3 hr 1/2 hr 1-3/4 hr 3/4 hr 1/4hr 3hr 1/2 hr 1-1/4 hr 1/2 hr Activity Circulated at 11037.0 ft Drilled to 12048.0 ft Circulated at 12048.0 ft Drilled to 12246.0 ft Circulated at 12246.0 ft Drilled to 12261.0 ft Drilled to 13000.0 ft Drilled to 13372.0 ft Circulated at 13372.0 ft Pulled out of hole to 11900.0 ft Serviced Block line R.I.H. to 13372.0 ft Circulated at 13372.0 ft Circulated at 13372.0 ft Pulled out of hole to 204.0 ft Pulled BHA Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Tested BOP stack Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 16 R.I.H. to 5820.0 ft Circulated at 5820.0 ft R.I.H. to 11920.0 ft Reamed to 12185.0 ft R.I.H. to 13372.0 ft Circulated at 13372.0 ft Pulled out of hole to 576.0 ft Pulled BHA Held safety meeting Rigged up sub-surface equipment - Formation logs Rigged up sub-surface equipment - Formation logs Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down sub-surface equipment - Formation logs Installed Casing handling equipment Held safety meeting Ran Liner to 1509.0 ft (4-1/2in OD) Installed Tubing handling equipment Ran Tubing to 1475.0 ft (2-7/8in OD) Installed Liner hanger Circulated at 1681.0 ft Ran Drillpipe in stands to 7348.0 ft Circulated at 7348.0 ft Ran Drillpipe in stands to 9920.0 ft Held safety meeting Progress Report Facility Badami CPF Well Bl-16 Rig Nabors 28E Page 8 Date 07 July 98 Date/Time 10 Jun 98 11 Jun 98 12 Jun 98 13 Jun 98 00:00-01:30 01:30-02:30 02:30-03:15 03:15-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-07:30 07:30-08:00 08:00-08:30 08:30-12:00 12:00-12:45 12:45-19:30 19:30-21:30 21:30-21:45 21:45-01:30 01:30-02:00 02:00-03:30 03:30-04:15 04:15-06:00 06:00-07:30 07:30-15:15 15:15-17:30 17:30-18:15 18:15-18:30 18:30-05:15 05:15-05:30 05:30-06:00 06:00-06:30 06:30-09:45 09:45-10:00 10:00-12:30 12:30-14:15 14:15-14:45 14:45-15:00 15:00-15:30 15:30-15:45 15:45-17:15 17:15-18:45 18:45-19:30 19:30-21:30 21:30-22:30 22:30-23:00 23:00-23:45 23:45-00:30 00:30-01:00 01:00-01:45 01:45-02:00 Duration 1-1/2 hr 1 hr 3/4 hr 1-1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 3-1/2 hr 3/4 hr 6-3/4 hr 2hr 1/4 hr 3-3/4 hr 1/2 hr 1-1/2 hr 3/4 hr 1-3/4 hr 1-1/2 hr 7-3/4 hr 2-1/4 hr 3/4 hr 1/4 hr 10-3/4 hr 1/4 hr 1/2 hr 1/2 hr 3-1/4 hr 1/4 hr 2-1/2 hr 1-3/4 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr 1-1/2 hr 1-1/2 hr 3/4 hr 2hr 1 hr 1/2 hr 3/4 hr 3/4 hr 1/2 hr 3/4 hr 1/4 hr Activity Ran Drillpipe in stands to 11902.0 ft Circulated at 11902.0 ft Installed Cement head Ran Drillpipe in stands to 13379.0 ft Circulated at 13379.0 ft Circulated at 13372.0 ft Held safety meeting Tested Chicksan lines Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 42.000 bbl Displaced slurry - 92.000 bbl Circulated at 13285.0 ft Tested Liner Serviced Fluid system Fill pits with Brine Held safety meeting Circulated at 13285.0 ft Held safety meeting Tested Liner Removed Cement unit Laid down 900.0 ft of 3-1/2in OD drill pipe Laid down 1000.0 ft of 4in OD drill pipe Laid down 10000.0 ft of Drillpipe Laid down 1510.0 ft of Tubing Laid down 650.0 ft of Drill collar Serviced Wear bushing Ran Tubing to 11586.0 ft (4-1/2in OD) Installed Accessories Rigged down Tubing handling equipment Rigged down Bell nipple Repaired Annular preventor Held safety meeting Rigged up BOP stack Installed Wellhead primary components Tested Surface tree Rigged up High pressure lines Tested Surface tree Removed Well control Rigged up Flowline Circulated at 11584.0 ft Held safety meeting Circulated at 11584.0 ft Circulated at 11584.0 ft Functioned Permanent packer Tested Tubing Tested Permanent packer Rigged up Well control Removed Surface lines Rigged down High pressure lines RECEIVED JUN 2 Z 1998 BPXA PDC Badami Alaska State Plane Zone 3 Badami CPF B1.16 SURVEY REPORT 12 June, 1998 Your Ref: AP1'500292288000 Last Survey Date 06-June-98 Job # AKVCS0215 KBE- 54.30' CONFIDENTIAL Survey Ret~ svy2$2 Badami Measured Depth (ft) 3385.37 3481.56 3575.75 3671.68 3767.49 3861.75 3958.00 4052.84 4149.31 4244.56 4339.22 4434.58 4529.91 4625.95 4721.85 4818.06 4912.99 5OO8.49 5103.91 5199.24 5294.94 5386.19 5483.15 5578.09 5672.75 5768.15 5862.29 5958.00 6054.59 6149.75 Incl. 47.700 45.300 43.70O 40.300 41.800 42.500 43.9OO 46.800 46.0OO 44.600 44.9O0 45.200 45.600 46.700 47.100 46.900 46.700 46.400 45.900 44.900 46.200 46.300 45.9O0 46.200 46.600 46.600 47.4O0 48.400 48.200 48.900 8.600 9.100 7.600 357.700 351.200 352.300 352.200 351.200 353.4OO 353.300 353.900 356.OOO 356.800 358.50O 0.200 0.200 0.200 0.600 0.500 0.400 357.800 0.200 358.600 359.100 357.100 357.900 358.200 359.000 358.100 355.900 Sub-Sea Depth (ft) 3143.58 3209.79 3276.97 3348.33 3420.62 3490.50 3560.66 3627.31 3693.84 376O.83 3828.06 3895.44 3962.37 4028.91 4094.44 4160.05 4225.03 4290.71 4356.82 4423.75 4490.77 4553.88 4621.11 4687.00 4752.29 4817.84 4882.04 4946.21 5010.46 5073.46 Vertical Depth (ft) 3197.88 3264.09 3331.27 3402.63 3474.92 3544.80 3614.96 3681.61 3748.14 3815.13 3882.36 3949.74 4016.67 4083.21 4148.74 4214.35 4279.33 4345.01 4411,12 4478.05 4545.07 4608.18 4675.41 4741.30 4806.59 4872.14 4936.34 5000.51 5O64.76 5127.76 Sperry-Sun Drilling Services Survey Report for Bf-16 Your Ref: API.500292288000 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 491.08 N 189.20 E 5906912.40 N 364103.42 E 450.24 560.01 N 199.92 E 5906981.13 N 364115.38 E 2.523 516.22 625.33 N 209.52 E 5907046.26 N 364126.15 E 2.033 578.84 689.26 N 212.66 E 5907110.13 N 364130.44 E 7.753 641.23 751.81 N 206.53 E 5907172.78 N 364125.44 E 4.721 703.88 814,41 N 197.46 E 5907235.53 N 364117.49 E 1.079 767.10 879.69 N 188.57 E 5907300.96 N 364109.78 E 1.456 832.93 946.44 N 178.82 E 5907367.88 N 364101.23 E 3.148 900,36 1015.66 N 169.45 E 5907437.26 N 364093.10 E 1.848 970.15 1082.91 N 161.61 E 5907504.63 N 364086.47 E 1.472 1037.73 1149.14 N 154.19 E 5907570.98 N 364080.24 E 0.547 1104.23 1216.36 N 148.25 E 5907638.30 N 364075.51 E 1.590 1171.45 1284.10 N 143.99 E 5907706.10 N 364072.47 E 0.730 1238.88 1353.29 N 141.16 E 5907775.34 N 364070.88 E 1.715 1307.50 1423.31 N 140.37 E 5907845.36 N 364071.35 E 1.360 1376.57 1493.67 N 140.61 E 5907915.70 N 364072.86 E 0.208 1445.79 1562.87 N 140.86 E 5907984.89 N 364074.34 E 0.211 1513.88 1632.20 N 141.34 E 5908054.20 N 364076.07 E 0.437 1582.04 1701.01N 142.00 E 5908122.98 N 364077.97 E 0.529 1649.67 1768.88 N 142.53 E 5908190.84 N 364079.72 E 1.052 1716.40 1837.18 N 141.44E 5908259.14 N 364079.86 E 2.368 1783.82 1903.07 N 140.29 E 5908325.05 N 364079.89 E 1.903 1848.90 1972.93 N 139.57 E 5908394.90 N 364080.42 E 1.259 1917.80 2041.27 N 138.20 E 5908463.26 N 364080.27 E 0.494 1985.31 2109.77 N 135.92 E 5908531.79 N 364079.23 E 1.587 2053.15 2179.02 N 132.90 E 5908601.08 N 364077.45 E 0.609 2121.86 2247.83 N 130.55 E 5908669.92 N 364076.35 E 0.881 2190.01 2318.82 N 128.82 E 5908740.93 N 364075.89 E 1.215 2260.20 2390.91 N 127.00 E 5908813.05 N 364075.36 E 0.726 2331.50 2462.13 N 123.26 E 5908884.32 N 364072.90 E 1.882 2402.27 Comment Tie-on Survey Window Point Alaska State Plane Zone 3 Badami CPF Continued... 12 June, 1998 - ~8:09 - 2 - DrillQuest Badami Measured Depth (ft) 6245.37 6340.14 6434.65 6530.09 6624.46 6720.16 6815.88 6911.16 7005.56 7101.98 71'97.64 7294.48 7388.67 7484.52 7579.94 7674.78 7770.21 7865.97 7961.33 8056.97 8152.31 8248.53 8344.15 8440.19 8535.36 8630.44 8726.11 8821.59 8917.40 9011.89 Incl. 49.600 49.700 49.70o 48.70o 48.200 47.400 46.8oo 46.200 45.8oo 45.700 45.600 45.90o 45.400 46.5o0 46.200 46.5oo 46.900 46.5OO 46.300 47.200 47.200 46.700 47.10o 46.600 45.9OO 45.200 44.600 45.800 46.000 46.600 Azim, 355.100 352.700 351.900 349.200 349.5OO 346.800 345.9OO 345.300 343.900 342.7O0 341.400 34O.6OO 339.200 339.000 341.000 341.600 344.700 344.700 344.2O0 343.400 345.200 343.700 344.6OO 344.400 344.3O0 344.400 342.9OO 344.500 343.60O 341.800 Sub-Sea Depth (ft) 5135.87 5197.24 5258.37 5320.74 5383.33 5447.62 5512.78 5578.36 5643.94 5711.22 5778.10 5845.67 5911.51 5978.16 6044.02 6109.49 6174.94 6240.62 6306.38 6371.91 6436.69 6502.38 6567.71 6633.39 6699.20 6765.79 6833.56 69OO.84 6967.51 7O32.80 Vertical Depth (ft) 5190.17 5251.54 5312.67 5375.O4 5437.63 5501.92 5567.08 5632.66 5698.24 5765.52 5832.40 5899.97 5965.81 6032.46 6O98.32 6163.79 6229.24 6294.92 6360.68 6426.21 6490.99 6556.68 6622.01 6687.69 6753.50 6820.09 6887.86 6955.14 7021.81 7087.10 Sperry-Sun Drilling Services Survey Report for B'l.16 Your Ref: API-500292288000 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/t00ft) (ft) 2534.35 N 117.57 E 5908956.63 N 364068.51 E 0.968 2474.36 '2606.15 N 109.90 E 5909028.56 N 364062.13 E 1.933 2546.39 2677.58 N 100.24 E 5909100.15 N 364053.76 E 0.646 2618.41 2748.84 N 88.39 E 5909171.61 N 364043.19 E 2.384 2690.64 2818.24 N 75.34 E 5909241.24 N 364031.39 E 0.581 2761.26 2887.62 N 60.80 E 5909310.86 N 364018.09 E 2.251 2832.11 2955.76 N 44.25 E 5909379.28 N 364002.77 E 0.931 2902.09 3022.70 N 27.06 E 5909446.52 N 363986.79 E 0.778 2971.01 3088.16 N 9.04 E 5909512.30 N 363969.94 E 1.148 3038.63 3154.31 N 10.81W 5909578.80 N 363951.29 E 0.897 3107.23 3219.39 N 31.89W 5909644.24 N 363931.38 E 0.977 3175.00 3284.97 N 54.47W 5909710.22 N 363909.98 E 0.668 3243.53 3348.22 N 77.62W 5909773.88 N 363887.98 E 1.188 3309.86 3412.58 N 102.19W 5909838.66 N 363864.56 E 1.157 3377.53 3477.45 N 125.81W 5909903.95 N 363842.12 E 1.549 3445.54 3542.45 N 147.81VV 5909969.33 N 363821.29 E 0.556 3513.39 3608.91 N 167.93W 5910036.14 N 363802.36 E 2.401 3582.35 3676.13 N 186.32W 5910103.68 N 363785.18 E 0.418 3651.75 3742.66 N 204.83W 5910170.53 N 363767.87 E 0.434 3720.50 3809.55 N 224.27W 5910237.76 N 363749.64 E 1.121 3789.76 3876.89 N 243.20W 5910305.43 N 363731.92 E 1.385 3859.38 3944.62 N 262.04W 5910373.50 N 363714.30 E 1.252 3929.37 4011.79 N 281.11W 5910440.99 N 363696.44E 0.805 3998.84 4079.31 N 299.83W 5910508.83 N 363678.93 E 0.542 4068.60 4145.50 N 318.38W 5910575.35 N 363661.58 E 0.739 4137.02 4210.86 N 336.69W 5910641.03 N 363644.45 E 0.740 4204,58 4275.66 N 355.69W 5910706.16 N 363626.61 E 1.272 4271.71 4340.68 N 374.70W 5910771.51 N 363608.78 E 1.730 4339.06 4406.84N 393.60W 5910838.00 N 363591.06 E 0.706 4407.50 4472.05 N 413.92W 5910903.57 N 363571.92 E 1.517 4475.27 Comment Alaska State Plane Zone 3 Badami CPF OON.FIDENTIAL Continued... 12 June, 1998 - 18:09 - 3 - DrillQuest Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 9107.89 46.800 343.100 7098.64 7152.94 9202.78 46.500 343.500 7163.77 7218.07 9298.87 46.200 343.100 7230.10 7284.40 9394.26 45.700 343.400 7296.42 7350.72 9489.66 46.100 343.400 7362.81 7417.11 9585.42 45.700 343.500 7429.45 7483.75 9681.05 45.500 344.200 7496.36 7550.66 9776.97 45.100 343.200 7563.83 7618.13 9872.38 44.900 342.500 7631.30 7685.60 9968.78 45.300 342.800 7699.34 7753.64 10062.86 44.400 343.900 7766.04 7820.34 10159.41 44.200 343.600 7835.14 7889.44 10255.04 44.300 342.900 7903.64 7957.94 10349.14 43.200 344.400 7971.62 8025.92 10443.92 43.200 343.000 8040.71 8095.01 10541.28 42.500 343.900 8112.09 8166.39 10636.03 42.300 342.000 8182.06 8236.36 10731.36 41.700 342.500 8252.91 8307.21 827.57 40.900 341.000 8325.19 8379.49 922.77 39.800 338.800 8397.74 8452.04 11017.71 39.300 338.400 8470.95 8525.25 11113.66 38.500 336.900 8545.62 8599.92 11209.03 37.200 337.300 8620.92 8675.22 11305.60 35.600 338.000 8698.65 8752.95 11399.91 34.000 337.800 8776.09 8830.39 11495.69 32.700 337.500 8856.10 8910.40 11591.22 31.500 336.800 8937.02 8991.32 11687.15 30.400 337.100 9019.29 9073.59 11782.69 29.100 335.900 9102.24 9156.54 11879.40 28.200 332.500 9187.11 9241.41 Sperry-Sun Drilling Services Survey Report for Bl-16 Your Ref: API-500292288000 Local Coordinates Global Coordinates Dogleg Vertical- Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4538.66 N 434.99W 5910970.55 N 363552.05 E 1.007 4544.55 4604.75 N 454.82W 5911036.98 N 363533.41 E 0.440 4613.09 4671.35 N 474.79W 5911103.92 N 363514.63 E 0.434 4682.16 4737.00 N 494.55W 5911169.92 N 363496.06 E 0.571 4750,26 4802.65 N 514.13W 5911235.91 N 363477.67 E 0.419 4818.33 4868.57 N 533.71W 5911302.17 N 363459.27 E 0.424 4886.66 4934.20 N 552.72W 5911368.13 N 363441.44 E 0.563 4954.61 4999.64 N 571.85W 5911433.90 N 363423.49 E 0.850 5022.39 5064.10 N 591.75W 5911498.72 N 363404.76 E 0.560 5089.34 5129.28 N 612.11W 5911564.25 N 363385.57 E 0.470 5157.08 5192.84 N 631.12W 5911628.14 N 363367.70 E 1.263 5223.00 5257.58 N 649.99W 5911693.21 N 363350.00 E 0.300 5290.04 5321.48 N 669.22VV 5911757.44 N 363331.92 E 0.521 5356.32 5383.91 N 687.55VV 5911820.20 N 363314.72 E 1.607 5421.00 5446.18 N 705.76W 5911882.78 N 363297.63 E 1.011 5485.50 5509.65 N 724.62W 5911946.58 N 363279.91 E 0.955 5551.30 5570.73 N 743.35W 5912007.98 N 363262.28 E 1.369 5614.71 5631.48 N 762.80W 5912069.07 N 363243.93 E 0.721 5677.93 5691.78 N 782.68VV 5912129.72 N 363225.14 E 1.323 5740.79 5749.66 N .803.84W 5912187.97 N 363205.01 E 1.890 5801.49 5805.94 N 825.90W 5912244.64N 363183.97 E 0.591 5860.77 5861.67 N 848.80W 5912300.77 N 363162.07 E 1,288 5919.65 5915.57 N 871.58W 5912355.08 N 363140.27 E 1.387 5976.72 5968.57 N 893.37W 5912408.46 N 363119.43 E 1.712 6032.71 6018.44N 913.62W 5912458.68 N 363100.08 E 1.701 6085,36 6067.14 N 933.64W 5912507.73 N 363080.94 E 1.368 6136.82 6113.92 N 953.35W 5912554.86 N 363062.07 E 1.315 6186.33 6159.31 N 972.67W 5912600.59 N 363043.57 E 1.158 6234.42 6202.79 N 991.56W 5912644.40 N 363025.46 E 1.497 6280.54 6244.53 N 1011.72W 5912686.50 N 363006.06 E 1.925 6325.16 Comment Alaska State Plane Zone 3 Badami CPF CONFIDENTIAL Continued... 12 June, 1998 - 18:09 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for Bl-16 Your Ref: AP1-500292288000 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical- Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 11955.69 27.700 333.100 9254.50 9308.80 6276.33 N 1028.06 W 5912718.59 N 362990.29 E 0.752 6359.34 12049.30 26.500 333.900 9337.83 9392.13 6314.49 N 1047.09 W 5912757.08 N 362971.95 E 1.340 6400.25 12144.18 25.300 335.700 9423.18 9477.48 6351.98 N 1064.75 W 5912794.88 N 362954.97 E 1.512 6440.26 12238.99 24.200 334.200 9509.28 9563.58 6387.94 N 1081.55 W 5912831.14 N 362938.82 E 1.336 6478.61 12333.67 23.600 335.000 9595.85 9650.15 6422.59 N 1098.00 W 5912866.08 N 362922.99 E 0.720 6515.61 12427.82 22.700 335.700 9682.41 9736.71 6456.23 N 1113.44 VV 5912899.99 N 362908.16 E 1.000 6551.43 12521.74 21.500 337.700 9769.43 9823.73 6488.67 N 1127.43 W 5912932.68 N 362894.75 E 1.508 6585.83 12616.26 20.700 338.900 9857.62 9911.92 6520.28 N 1140.02 W 5912964.51 N 362882.74 E 0.962 6619.16 12710.68 20.200 338.500 9946.09 10000.39 6551.02 N 1152.00 W 5912995.46 N 362871.31 E 0.550 6651.52 12805.87 19.500 341.000 10035.62 10089.92 6581.33 N 1163.20 W 5913025.97 N 362860.66 E 1.156 6683.33 12900.59 18,800 339.700 10125.10 10179.40 6610,59 N 1173.64 W 5913055.41 N 362850.74 E 0.865 6713.97 12994.18 17.600 338.900 10214.01 10268.31 6637.94 N 1183.96 W 5913082.94 N 362840.91 E 1.310 6742.70 13089.26 16.200 340.900 10304.98 10359.28 6663.89 N 1193.48 VV 5913109.05 N 362831.86 E 1.594 6769.91 13183.88 15.300 339.900 10396.04 10450.34 6688.08 N 1202.09 W 5913133.40 N 362823.69 E 0.993 6795.25 13279.03 14.300 340.900 10488.04 10542.34 6710.98 N 1210.25 W 5913156.44 N 362815.94 E 1.085 6819.22 13303.05 14.000 340.200 10511.33 10565.63 6716.51 N 1212.20 W 5913162.01 N 362814.09 E 1.438 6825.01 13372.00 13.300 339.900 10578.33 10632.63 6731.81 N 1217.75 W 5913177.40 N 362808.81 E 1.020 6841.04 ,All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. 'Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 349.890° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13372.00ft., The Bottom Hole Displacement is 6841.06ft., in the Direction of 349.746° (True). Comment Projected Survey Alaska State Plane Zone 3 Badami CPF CONFIDENTIAL Continued... 12 June, 1998 - 18:09 - 5 - DrillQuest Badami Sperry-Sun Drilling Services Survey Report for Bl-16 Your Ref: API-500292288000 Alaska State Plane Zone 3 Badami CPF Comments Measured Depth (ft) 3385.37 3481.56 13372.00 Station Coordinates TVD Northings Eastings (ft) (ft) {ft) 3197.88 491.08 N 189.20 E 3264.09 560.01 N 199.92 E 10632.63 6731.81 N 1217.75 W Comment Tie-on Survey Window Point Projected Survey CONFIDENTIAL 12 June, 1998 - 18:09 - 6 - DrillQuest RECEIVED JUN 2 2 B98 BPXA PDC .Badami Alaska State Plane Zone 3 Badami CPF B~.~6PB~ S UR VEY REPORT June, ~998 Your Ref: AP1-500292288070 l_ast Survey Date 09-May.98 Job # AKVC80214 KBE. 54.30' DRILLING SERVICES CONFIDENTIAL Survey Ref: svy250 Badami Measured Depth fit) 542.00 632.72 719.76 812.03 907.41 994.30 1087.97 1179.94 1272.48 1362.03 1455.65 1548.95 1640.21 1731.79 1821.83 1914.99 2006.39 2097.51 2187.51 2280.79 2368.29 2462.38 2554.39 2647.57 2740.24 2831.57 2924.25 3016.86 3107.85 3200.06 Incl. 0.100 1.300 2.200 3.700 5.500 8.300 9.700 9.600 8.400 6.700 4.800 3.200 2.500 2.000 3.400 4.500 5.900 9.000 12.700 13.900 16.300 20.600 24.100 28.000 30.300 32.400 35.300 37.200 37.900 41.000 Azim. 256.500 183.600 200.600 184.900 179.600 182.300 178.700 177.200 180.500 180.000 180.600 186.300 215.900 283.200 331.300 354.500 3.500 16.300 26.900 31.900 35.200 37.400 35.500 29.400 25.400 22.300 17.200 14.700 11.300 7.400 Sub-Sea Depth (ft) 487.68 578.40 665.39 757.54 852.61. 938.86 1031.38 1122.05 1213.45 1302.22 1395.36 1488.43 1579.58 1671.11 1761.05 1854.00 1945.02 2035.37 2123.75 2214.53 2299.00 2388.24 2473.32 2557.04 2637.97 2715.97 2792.95 2867.63 2939.78 3010.98 Vertical Depth fit) 541.98 632.70 719.69 811.84 906.91 993.16 1085.68 1176.35 1267.75 1356.52 1449.66 1542.73 1633.88 1725.41 1815.35 1908.30 1999.32 2089.67 2178.05 2268.83 2353.30 2442.54 2527.62 2611.34 2692.27 2770.27 2847.25 2921.93 2994.08 3065.28 Sperry-Sun Drilling Services Survey Report for Bl-16PB1 Your Ref: API-500292288070 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) fit) (ft) fit) (o/looft) fit) 1.74 N 3.45W 5906426.60 N 363902.01E 2.32 0.69 N 3.59W 5906425.56 N 363901.85 E 1.405 1.31 1.86 $ 4.24W 5906423.02 N 363901.16 E 1.183 -1.08 6.48 S 5.12W 5906418.41N 363900.20 E 1.832 -5.48 14.12 $ 5.35W 5906410.78 N 363899.83 E 1.937 -12.96 24.55 S 5.57W 5906400.35 N 363899.42 E 3.243 -23.19 39.20 S 5.66W 5906385.71N 363899.06 E 1.610 -37.60 54.60 S 5.11W 5906370.30 N 363899.34 E 0.294 -52.86 69.07 S 4.80W 5906355.83 N 363899.39 E 1.411 -67.16 80.84 S 4.85W 5906344.06 N 363899.13 E 1.900 -78.73 90.22 S 4.89W 5906334.69 N 363898.92 E 2.030 -87.96 96.71S 5.22W 5906328.20 N 363898.47 E 1.765 -94.29 100.85 S 6.67W 5906324.08 N 363896.95 E 1.759 -98.12 102.10 S 9.39W 5906322.88 N 363894.20 E 2.760 -98.87 99.40 S 12.21W 5906325.63 N 363891.44 E 2.826 -95.72 93.34S 13.88W 5906331.72 N 363889.87 E 2.059 -89.46 85.08 S 13.94W 5906339.98 N 363889.96 E 1.768 -81.32 73.56 S 11.65W 5906351.46 N 363892.46 E 3.839 -70.38 57.98 S 5.20W 5906366.92 N 363899.19 E 4.654 -56.17 39.32 S 5.36 E 5906385.39 N 363910.08 E 1.781 -39.65 20.36 S 18.00 E 5906404.12 N 363923.06 E 2.912 -23.20 3.59 N 35.67 E 5906427.75 N 363941.16 E 4.629 -2.73 31.75 N 56.42 E 5906455.53 N 363962.41 E 3.884 21.35 66.31 N 78.21 E 5906489.70 N 363984.82 E 5.073 51.55 106.39 N 98.92 E 5906529.40 N 364006.25 E 3.252 87.38 149.85 N 118.09 E 5906572.50 N 364026.20 E 2.899 126.79 198.42 N 135.44E 5906620.76 N 364044.41 E 4.378 171.57 251.07 N 150.46 E 5906673.13 N 364060.38 E 2.599 220.76 305.09 N 162.92 E 5906726.91 N 364073.80 E 2.403 271.75 362.88 N 172.37 E 5906784.53 N 364064.29 E 4.303 326.99 Comment Tie-on to Surface Gym Alaska State Plane Zone 3 Badami CPF CO. NFIDENTIAL Continued... 12Jun~ 1998 - 17:49 - 2 - DdilQuest Sperry-Sun Drilling Services Survey Report for Bl-16PB1 Your Ref: AP1-500292288070 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical- Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/t00ft) (ft) 3289.71 44.100 6.900 3077.02 3131.32 423.03 N 179.90 E 5906844.53 N 364092.90 E 3.478 384.88 3385.37 47.700 8.600 3143.58 3197.88 491.08 N 189.20 E 5906912.40 N 364103.42 E 3.974 450.24 3480.76 48.300 10.900 3207.42 3261.72 560.93 N 201.21 E 5906982.02 N 364116.68 E 1.899 516.90 3576.72 49.600 12.300 3270.43 3324.73 631.81 N 215.76 E 5907052.63 N 364132.51 E 1.745 584.13 3671.70 48.200 13.100 3332.87 3387.17 701.63 N 231.49 E 5907122.16 N 364149.49 E 1.605 650.10 3767.82 46.200 9.300 3398.19 3452.49 770.78 N 245,22 E 5907191.05 N 364164.46 E 3.569 715.77 3863.25 43.100 8.400 3466.07 3520.37 837.04 N 255.56 E 5907257.11 N 364175.98 E 3.315 779.18 3953.14 41.200 6,700 3532,71 3587.01 896.83 N 263.50 E 5907316.75 N 364185.00 E 2.465 836.65 4052.36 40.400 3.900 3607.83 3662.13 961.37 N 269.50 E 5907381.17 N 364192.15 E 2.012 899.13 4150.17 41.000 6.200 3681.99 3736.29 1024.89 N 275.12 E 5907444.58 N 364198.92 E 1.651 960.68 4244.61 42.000 4.900 3752.72 3807.02 1087.17 N 281.16 E 5907506.75 N 364206.08 E 1,398 1020.94 4339.80 43.800 3.400 3822.45 3876.75 1151.79 N 285,84 E 5907571.27 N 364211.91 E 2.174 1083.73 4434.92 44.500 3.500 3890.70 3945.00 1217.93 N 289.82 E 5907637.33 N 364217.09 E 0.740 1148.14 4531.88 44.000 359.800 3960.16 4014.46 1285.53 N 291.78 E 5907704.88 N 364220.26 E 2.712 1214.35 4627.42 44.500 358.900 4028.60 4082.90 1352.20 N 291.02 E 5907771.55 N 364220.70 E 0.840 1280.11 4722.61 44.900 0.000 4096.26 4150.56 1419.15 N 290.38 E 5907838.50 N 364221.26 E 0,915 1346.14 4839.00 44.900 0.000 4178.70 4233.00 1501,30 N 290.38 E 5907920.64 N 364222.74 E 0.000 1427.02 ,,All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. ,'Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 349.890° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4839.00ft., The Bottom Hole Displacement is 1529.13ft., in the Direction of 10.947° (True). Comment Projected Survey Alaska State Plane Zone 3 Badami CPF CONFIDENTIAL Continued... 12 June, 1998 - 17:49 - 3 - DrillQuest Badami Sperry-Sun Drilling Services Survey Report for Bl-16PBl Your Ref: API-500292288070 Alaska State Plane Zone 3 Badami CPF Comments Measured Depth (ft) 542.00 4839.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 541.98 1.74 N 3.45 W 4233.00 1501.30 N 290.38 E Comment Tie-on to Surface Gyro Projected Survey CONF DENTIAL 12 June, 1998 - 17:49 - 4 - DrillQuest 13425.tmp created Thu Jul by CLEANUP Vl.0 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 9 JUL 98 ISL Input File Name - 13425 ISL 9 11:26:11 1998 File 1 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 11934.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - File 1 - Log Header Information + -0.0 (F) LOG HEADER LISTING Page 1 -+ Log Heading: SEGMENTED BOND TOOL Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-16 BADAMI NORTH SLOPE ALASKA Sec: Twp: Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11928.0 11926.0 11926.0 10470.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0 0 0. 0 .0 .0 O0 .0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: KCL/POLYMER 0.00 0.00 0.00 0.00 0.000 0.000 Rge: Elevations:- KB: 0.0 DF: 0.0 GL: 0.0 0.0 0.0 0.00 0.0 Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: + .... ISL ........ 0.000 0.000 at 0.000 at 0.000 1030. 000000000000000 0.0 3880T BADAMI 150. 0000000000000000 E. MURPHY NICK SCALES ISL .... + LOG HEADER LISTING ................. Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. Other Services:- NONE Equipment Numbers:- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 GR 1 1 ServID Stat InUnit OutUnit LIS 01 ALLO F F LIS 01 ALLO GAPI GAPI Start 11934.000 -999.250 Stop -0.000 -127.737 File 1 - Comments Listing File does not contain any c 10/28/99 08:03 I,'AX 907 5645136 B P I T STATE OF ALASKA ...... ; ALASKA OIL AND GAS GONSERVAT1ON GOMMISSION REPORT OF SUNDRY WELL OPERATIONS [~008 il. Operations performed: r~__~ Operation Shutdown I~, Stimulate [] Pluogingv l~ Perforate [~] Pull Tubing i--IAIter Casing [] Repair Well '~ Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surfa,..-~ 3R55' NSL, 107' WEL, SEC. 8, TgN, R20E, UM At top of productive intc, rval 5221' NSL, 1294' WEt. SEC. 32, T10N, R20E, UM At effective depth 76' NSL, 183' EWL, SE(?. 4, T9N, R20E, UM At total depth 27' NSL, 1325' WEL, S!!C. 32, TION, R20E, UM Type of well: .,~ Development E~ Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 54.3' 7. Unit or Property Name Badami Unit 8. Well Number B1-16 9. Permit Number / Approval No. 98-80 10. APl Number 50-029-22880 11. Field and Pool Badami Field / Badami Oil Pool 12. Present well condition summary Total depth: measured 13372 feet true vertical 10633 feet Effective depth: measured 13286 feet true vertical 10549 feet Casing Length Size Structural Conductor 73' 20" Surface 5342' 9-5/8" Intermediate 11895' 7" Production Liner 1620' Plugs (measured) Junk (measured) Cemented MD TVD 260 sx ArcticSet (Approx.) 2924 sx PF 'E', 385 sx Class 'G' 200 sx Class 'G' 110' 110' 5377' 2198' 11928' 9398' 4-112" 205 sx Class 'G' 11752' - 13372' 9130' - 10633' Perforation depth: mea.~ured 12770' - 12828', 13080' - 13104', 13130' - 13190' truevedical 10057'-10112', 10351'-10374', 10399'-10457' 0P, i 01NAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 11586' Packers and SSSV (type and measured depth) HES TNT packer at 11557'; HES HXO SSSV landing nipple at 2208' 13. Stimulation or cement ~queeze summary Intervals treated (meas~,red) 13154' - 13174' Treatment description including volumes used and final pressure Hydraulic propped fracture, placed 87,000# sand behind pipe. OCT £ 8 1999 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl 260 !30 Casing Pressure Tubing Pressure 15. Attachments } 16. Status of well classifications as: ~ Copies of Logs and Surveys run l, ;~ Oil [] Gas [] Suspended Service ~ Daily Report of Well q)perations l Bill Turnbull Title Sr. Petroleum Engineer, ENS Prepared By Nam e/Number: Biff Tumbul/, 564-4662 Form 10-404 Rev. 06/15/88 Submit In Duplicate 10/28/99 08:04 F..\X 907 5{;45136 BP IT CTR [~;]009 BADAMI. ALASKA TO: Mark Sauve i'ROM: Pat Coliins Well !~ame: Bl-16 Main C(~tegory: FRAC Sub Ccltegow: Frac Pe,ff Operation Da'~e: 9/1,5/98 ]..i ..... _ III · I I Dot : "I B1-16 Frac Petfs Reperforated 20 fl with big hole charges for the upcoming frac. Perforated Ruff1 13154 -13174 fl md bkb, 20ftgun Well was loaded with diesel, WHSIP 3400 psi. Shot with well on balance. Comments: The intervals w~re perforated with deep penetrating charges. fie in log/date: SBT 3/20/98 fD Tag: TD not tagged Chc~rge Type: Big hole charges ----Interval Measured Depth .... Top Ft. Base Ft. Gun Dia. Shot Density Orientation Phasinq 13154 ._ .13174 2 3/,,, " i 6 siof random 60 degrees 10/28/9.q 08:04 FAX .907 5645136 I~P IT Crl~ ~010 Page BP EXPLORA ['ION (ALASKA)INC. Badami TO: Mark; ;auve FROM- Pat Collins DATE: September 1 7, 1998 RE: B1-16 FRAC SERVICE CO'S.' Dowell, Halliburton, Peak, HB&R ,_ t JOB SUMMARY Pumped a 300 bbl data frac. Pressure decline showed multiple closures. Analysis gave a leakoff of .OO33. The job was redesigned for 150 Mlbs 20/40 CL. Called flush early when surface pressures indicated screenout starling. Pumped 86.7 Mlbs to the formation, left 1 Mlbs in the tubing. INJECTIVITY TEST Bbls Max Rate, Final STP [ 1SIp, NWB friction, Treat grad, Pumped bpm psiI P SI psi psi/ft 100 20 4480 I 3230 170 .76 Design Rate, ! 13PM 20 .. DATA FRAC Bbls Pumped Bbls XL gel I Time XL gel b.~ Perfs ~ on perfs 300 300 i 15 4370 Final STP. i ISIP, psi I NWB i Treat grad, psi i [ friction, psi j psilft i 3280 I 0 i .76 DATE/TIME OPERATIONS SUMMARY 9tl 5/98 19:00 Barge arrived. Unload barge. Spot 5 tiger tanks and complete berm. Spot silo. Haul seawator ovornight to fill tanks. Heat seawater to 100 degrees with HB&R. 9/16/98 07:00 '~ Rig up remaining frac equipment. Load sand. Continue to haul and heat seawater. 9/17/98 06:00 06:30 07:30 108:55 Hold PJSM. Check area. Test fluids. Prime turbines. 10/28/99 (18:114 FAX 907 5645136 BP IT CTR ~011 P age 2 PUMPING SUMMARY STAGE! CUM i COMMENTS BBL I BBL i TIME I RATE t ANNP! WHP I" BPM I PSIG i PSIG IiN,IECTMqI' Y TEST DISPLACE~IENT = 200 BBLS 09:25 i 0 o.9:42i 2 I " 2O 0 2990( 4000 I 3200i " 4325 " !4200 " ]4660 " 4980 I 0 0 Open well. Set tree saver. Pressure test to 9700 psi. Pressure annulus to 4000 psi. 0 0 Start x-linked at 2 bpm 4 2O 4O 6O " i 52.6_0 80 " ~ 5630 ' 100/0 'Ii ~ " _ 5300 30~0 " '4380 70 '" 149901 100 4 130 175 305 Saw possible breakdown at 4325 psi. Bring rate up to 5 bp. Activator at 6 pptg. Xlink in 4 rains I Xlink in 1.5 rains. Very strong gel. Activator at 6 t jgm.g. X-link in 1.5 mins. Switch to linear .gel. Switch to seawater. Gel on perfs. Increase rate to 20 bpm Shut down. ISIP 3230 psi. Low NWBF. DATA FRAC 150 Stad data frac. Displace to perfs at 10 bpm. Activator added at 4 gptg. Xlink 3 rains. Gel much better than Inlectlvity. t " i 5190 ! Xlink in 3 mins " Drop rate to 5 bpm " Xlink time 3 mins Gel on perfs. Increase rate to 20 bpm. i 5360 I 175 6400 ¢ 185 6620 200 6230, 250 6000 i 300/0 i593030/0 5480i 100 5000 150 4370i 175 505 Switch to linear gel Switch to seawater Shut down and monitor decline. ISIP 3280 psi. 10/28/99 08:04 FAX 907 5645136 BP IT CTR [~012 · Page 3 FRAC 9/17/98 '~ I i Data frac gave a leakoff of .0033. Redesigned ...... ~ I i' lob for 167 bbl pad and 150 Mlbs proppant. 17:15 i _i : i H°ldPJSM .... 17:30 0 I . 2770i i...' Prime up pumP' 17:40 I 10 I 4300 " :. 0 : 0 i Start X-link downho!e i " i i 23 [! Tree saver leaking down relief line. , , 35/0 Flush xlinked fluids out of surface lines. Pull tree ' . saver - rubbers torn on south side. Replace. 1905 i i ' : ISet tree saver' Pressure test t°12'300 psi' 19:30 _ " . .. 0 0 Start xlink down well " "[" , 4560 , 100'[ Xlinktime3mins. Goodgel _ " "! li5200 167/0 i t Start I ppg stage. Increase annulus pressure to ] i ! 5000 psi. t 20 I 5000 20 . ~g7 Increase rate to 2O bpm. - " " ... I " 5650I!13/0 . , Start3p. p_gstage " ! " ' 5600 i 25/0 Start 4 ppg stage I , "___i " 5420 40/0 Start 5. ppg s.t.age "[ ,, I5340 i 54/0 [ Start6 pgstage. 1 ppg on perfs ,. " ~" , 5090 , 68/0 , Start 7 ppg stage " I "I I 14770. 81/0 Sta. rt:.8 pp.g stage " : " 4610 I 94/0 I Start9 ppg stage I " ~ 44/0I WHP starting to turn. Call flush. 86,700 lbs away ~ " I ,, ~ 5220 50 ! i Displacement. Slipstreaming diesel. ~ " 5000 150 Shut down with 5 bbls uderdisplacement above 21:25 .... ~ top perf. ISIP 3290 psi. 40 bbls displaced as , ~ i freeze protect. 85,600 lbs to the perfs . 10/28/99 08:05 FAX 907 5645136 BP IT CTR ~013 .. Page 4 OPERATIONAL PROBLEMS · Barging went well and trouble free. · Tree saver r~bber gave out 23 bbls into the pad stage of the frac. This has been a consistent problem on these wells. Rubber seems cut on the same side and when pumping down seems to hang up perhaps on the tree valves. Could be a problem with the trees or wellhead. · PCM worked a treat. Gave good fluid and saved vatuable time mixing gel. · Fluid additiv~ recording was problematic. FLUIDS PUMP.17.D DOWNHOLE INJ TEST& DATA FRAC: 810 bbls TOTAL: 915 bbls ADDITIVES Base water seawater was seawater with 17,000 ppi Chlorides J877 (liquid gc..lling agent) 11.2 gptg J899 (activator) 4 gptg F75N (Surfactant) 1 gptg L10 (Boric acid XL) 2.2 gptg M275 (t}acteriacide) Adomite regain 40 ppt Broker: None in pad J218 0.1 ppt in slurry stages J475 0.5 ppt in 1 - 4 ppg stages 1.0 ppt in 5 - 10 ppg stages In injectivity, data frac and pad Activator was added at 6 gptg for the injectivity, but xlink time was 1.5 ins and the gel was very strong and brittle. For the data frac and frac it was added at 4 gptg. Both concentrations were tested in the lab before and looked good. 1(!/28/99 08:01 FAX 907 5645136 BP IT CTR ~001 ., BP EXPLORATION BP Exploration (Alaska)Inc, PO Box 196612 Anchorage, Alaska 99519-6612 Date: 10/28/1999 TELECOPY COMMUNICATIONS CENTER TO: Name: STEVE MCMAINS Company: AOGCC Location: Fax # 276-7542 Confirm # FROM: Name & Ex Michael x4657 Departmen Protech Data Center Mail Stop: MB 3-3 NOTES: STEVE, HERE ARE THE 403 & 404 ON B1-16 PAGES TO FOLLOW 2 (Does Not Include Cover Sheet) SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL For Communications Center Use Only Telecopy # 564-5500 Time In Time Sent BP EXPLORATION, Alaska Date: 10-07-98 Trans# 89647 BADAMi LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type RecType Rec Date Company Code Run Num Api Num B1-16 MWD DGR/EWR OH 07-Jun-98 SPERRY ' 10-12 500292288000 B1-16 MWD DGR/EWR OH 07-Jun-98 SPERRY 10-12 500292288000 B1-16 MWD EWR DISK 06-Jun-98 SPERRY 500292288000 Please sign and return one copy of this transmittal to: Carla Harris ,/,~~.~.. /,~ Petrotechnical Data Center -./._ , LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP - - 1 blueline BP--1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Evelyn Raybon Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-5-98 Trans# 89595 BADAMI CASED HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Trans Num SwName Log Type RecDate Company Code Run Num Apl Num 89595 B1-14 STATIC 21-Aug-98 ATLAS 4 500292287400 89595 B1-16 STATIC 20-Aug-98 ATLAS 1 500292288000 Lz~t.. 89595B1-11 PFC 07-Aug-98 ATLAS I 500292282900 Please sign and return one copy of this transmittal to: Carla Harris (~~ ~ Petrotechnical Data Center LOG DATA AOGCC- 1 blueline/1 sepia PETROFINA 1 blueline/1 sepia DNR - 1 blueline BP -- 1 blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska ... Date: 10-5-98 Trans# 89627 BADAMI CASED HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Trans Num Sw Name Log Type Rec Date Company Code Run Num Api Num 89627 B1-15 SPINNER/TEMP 09-Sep-98 ATLAS 1 500292287800 89627 B1-14 PFC 14-Sep-98 ATLAS 1 500292287400 89627 B1-16 PFC 15-Sep-98 ATLAS 1 500292288000 89627 B1-16 PFC 04-Sep-98 ATLAS 1 500292288000 89627 B1-21 SPINNER/TEMP 09-Sep-98 ATLAS 11 500292280900 89627 B1-15 GAS LIFT SURVEY 09-Sep-98 ATLAS 1 500292287800 89627 B1-21 PFC 05-Sep-98 ATLAS 1 500292280900 IJ.~ c.89627 B1-11 PRODUCTION LOG 13-Sep-98 ATLAS 1 500292282900 Please sign and return one copy of this transmittal to: Carla Harris Petrotechnical Data Center LOG DATA AOGCC- 1 blueline/1 sepia PETROFINA 1 blueline/1 sepia DNR - 1 blueline BP - - 1 blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Petrotechnicai Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 0~q:02 I:..\.X~ .q07 5645136 BP IT CTR STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL [~003 1. Type of Reouest: [] Abandon ,'--'] Suspend r-] Plugging [] Time Extension U Perforate [_~ Alter C2sm= [] Repair Wet! ~ Pull Tubing ~ Variance · ~_~ Other b_~ Change AcC)roved Program ~._~ Operation Shutdown ~ Re-Enter Sussended Well [] Stimulate 2. Hame of Operator BP Exnioration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 995t9-6612 Type of we:i: ~ Development !~ Exploratory ~ Strati0raphic 4, Locatioq of well at surface 3855' NSL, 107' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 5221' NSL, 1294' WEL, SEC. 32, TION, R20E, UM At effective depth 76' NSL, 183' EWL, SEC. 4. T9N, R20E, UM At total depth 27' NSL, 1325' WEL, SEC. 32, TION, R20E, UM 6. Datum Elevation (DF or KB) KBE = 54.3' 7. Unit or Property Name Badami Unit 8. Well Number B1-16 9. Permit Number : 98-80 10. APl Number 50-029-22880 11. Field and Pool Badami Field / Badami Oil Pool 12. Present well condition summary Total depth: measured 13372 feet Plugs (measured) true vertical 10633 feet Effectwe depth: measured 13286 feet Junk (measured) true vert. ical 10549 feet ORIGINAL Casing Length Size Cemented Structural Conductor 73' 20" 260 sx ArcticSet (Approx.) Surface 5342' 9-5/8" 2924 sx PF 'E', 385 sx Class 'G' Intermediate 11895' 7" 200 sx Class 'G' Production Liner 1620' 4-1/2" 205 sx Class 'G' MD TVD 1!0' 110' 5377' 2198' 11928' 9398' 11752'-13372' 9130'-10633' Perforation depth: measured 12770' - 12828', 13080' - 13104', 13130' - 13190' true vertical 10056' - 10111 ', 10350' - 10373', 10398' - 10456' Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, L-80 at 11586' Packe's and SSSV (type and measured depth) ECE VFD 0 CT ? 8, t999 ~J~sl~ 0il & Gas 00ns, O0r~Bissi0r~ Anchorage HES TNT packer at 11557" PES HXO SSSV landing n;pple at 2208' 13. Attachments 14. Estimated date for commencing operation September 17, 1998 16. If proposal was verbally approved ,.- blame of approver Date approved Conlacf Engireer Name/Number: Bill Tumbull, 564-4662 17.Signedl hereby certify theft h~~,~ ~ EHII Tumbull ~, ,~ Description summary of proposal I 15. Status of well classifications as: (~ Oil T-~ Gas F-] Suspended Service Preoared Dy Name/Nurhber: Detailed operations program b_J BOP sketch ~_ ifl Turnbull, 564-4662 true and correct to the best of my knowledge Title Sr. Petro!eum Engineer, ENS Date -( Commission Use Only Conditions of Approval: Notify Commission so representative may witness 1 Approval No.J Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission U(igli"!SJ .~lgll,.,.,O i~y Commissioner Date -' Form 10-,~03 Rev. 06115188 ~3.~;-"[~ '~; "~" ~,,'~. d~ih~LOR Submit In Triplicate Approved Copy Returned 10,' 28 ,' .gg 08:0~ I.'..\X §07 5~'-1.5136 I]P It CTE ~004 EXPLORATION Memorandum To: P.Collins/J. Powers/M_Goodwin From: P.Collins AND PE Subject: BADAMI B1-16 Frac Programme Date: Sep 14, 1998 B1-1 4 was completed with a 4 1/2" cemented liner and 4 1/2" tubing. Frac equipment will be barged from West Dock to Badami. Seawater will be drawn from the Badami dock and heated by a hot oil truck. The CTU will be barged out after this and B1-14 fracs are done if cleanouts are necessary, PTS frac separator is on location ready for flowback. 1. Reperforate 13154 - 13174 ft md bkb with big hole charges 2. Pump a 300 bbl data frac. 3. Redesign and pumo the frac. Initial calculations give 150,000 lbs 16/20 proppant. 4. Conduct a CTU cleanout if necessary. .5, Flow the we~l back througln the PTS flowback separator to clean up proppant. The Deviation across the perforated interval is 14°, at an azimuth of 340°, Attachments to this program ~nclude: · Well completion diagram. · Detaited data frac and propped frac program. · Tubing Movement Calculations for Welt B1-16. RECEIVED 0CT 2 8 1999 Naska. Oil a Gas Cons. Commisslor~ Anchorage 10,'28 .99 08'02 I:,,\,'( 907 gH4512, fi . PC L Purdom / R. Warner WSA Team Leader Wellfil~-. RECEIVED N~keOil & Gas Cons. C~mmissior~ Anchorage 10/28/99 0.~:05~ F.,\.~ 907 56~5136 BP iT CTR [~006 Badami B1-16 Frac proceedure Attention: Bob ] !~ayer / Wes Wilder DO NOT EXCEt_:D 8,400 surface pressure. Pre - Frac TreatTnent 1. Reperforate 13154- 13174 ft md bkb RECEIVED 0r,', po '-! -o 1999 & Gas Con . chomge . Shoot the guns on balance. Perforation should be with 2 ~,4" guns, 6 spf, 60 degree phasing, big hole charges. Pressure test annulus to 5,000 psi. Equipment will be brought out by barge from West Dock. Berm in and rig up eqdipment. Seawater will be taken from the Badami dock by vac truck. The water should be pumped into DS tiger tanks via a,3 mm filter and heated by hot oiler to i00 degrees F. OBjective: To create a frac of 250 feet Xfir~ the Badami A5 and J2 sands. Pump injectivi(y test and datafrac followed by the main fracture treatment. I) Rig up and stab tree saver, (4" Cameron tree, 4 1/2" L-80 tubing). The surface pressure is estimated to be 5,000 psi for pad. Azimuth = 340° Deviation = 14" ~') Pressure test surface lines to 10,000 psi. Expected treating pressure is between 5,000 and 8,000 psi. Observe trip-out of each pump. After verifying the pump trips, ~eset the trips to 200 psi above maximum treating pressure, 8,400 psi. Perform iniectivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. With gel at the perfs, bring the rate up as fast as possible to 20 bpm. I.~isplace iniectivity with 30 bbls of 50# linear gel followed by seawater. Over displace all crosslinked fluid into the perfs by 5 bbts. Shut down and monitor the surface pressure for at least 15 minutes. If the near weiibore friction is > 1,000 psi pump a large fluid slug - 50 bbls and flush. Monitor the decline, if near wellbore friction still high, repeat the orocedure. Look at both the value and the rate of change of the near wellbore friction. If, required a proppant siug will then be pumped. Once near wellbore friction is ,-, 500 psi proceed to Datafrac. 4) Perform 300 bbl Data frac with crosslinked fluid: Pump data frac down to perforations at 5 bpm. With gel at the perfs, bring up rate as quickly as possible to 20 bpm. Over displace data frac by 5 bbls. Displace the data frac with 30 50 # linear gel followed by seawater. Stop pumping and monitor the pressure declin..'~. Transmit the data to Anchorage for interpretation. 5) Discu'.~s closures and leakoff with town. Redesign the TSP. Pump 150.000 lbs fracture treatment at 20 bpm c, er modified ramp. ?) Freeze protect the tubing with 30 bbls diesel. Fable 1 Volumes Volume to Topl'erfs 195 bbls Under Flush 5.0 bbls Flush 190 bbls Post - Frac Treatment 1. Determine l,roppant top with slickline if necessary. 2. If a clean o~Jt is necessary, it will be done once B1-16 and 14 are fracced and the frac equipment out of the way. A CTU will be barged from West Dock. Clean out Carboiite per established procedure. An additional programme ,.*/ill be prepared if the operation is necessary. 3. A PTS flowback separator is on location. Flow the well through the separator initially to clean up proupant. RECEIVED OCT 1999 10/28/99 08:02 I:.-\.~ 907 5645136 BI' IT CTR [~002 Bi= BXPLOR/~ION Memorandum To: From: Subject: Blair Wondzell Bill Tumbull 564-4662 Badami - 403/404's for Bl-14 and Bl-16 l~'racs Date: 9/27/99 Reference: AOGCC Blair, A review of our records has shown that 403's and the subsequent 404's for the September 1998 frac jobs on B 1- 1.4 and Bl-16 were not completed. To rectify, this situation I hereby attach them. Please call me ffany clarification is required. Regards. Bill Tumbult ECEIVED 1999 Cons. Commissior~ gnchorage STATE OF ALASKA ALASKA O'er. AND GAS CONSERVATION COMk-m,-,¢SlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing [--lAIter Casing [] Repair Well []Other 2. Name of Operator 15. Type of well: BP Exploration (Alaska)Inc. I E~ Development F-I Exploratory 3. Address [--] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [~ Service 4. Location of well at surface [] Operation Shutdown [] Stimulate [] Plugging [] Perforate 6. Datum Elevation (DF or KB) KB = 54.3' 7. Unit or Property Name Badami 8. Well Number 3855' NSL, 107' WEL, SEC. 8, T9N, R20E, UM At top of productive interval N/A At effective depth 5271' NSL, 4149' WEL, SEC. 34, T1 ON, R4E At total depth 27' NSL, 1325' WEL, SEC. 32, TloN, R20E, UM B1-16 9. Permit Number / Approval No. 90-80 398-245 10. APl Number 50-029-22880 11. Field and Pool Badami Field/Badami Oil Pool 12. Present well condition summary Total depth: measured 13372' true vertical 10633' Effective depth: measured 13286' true vertical 10549' Casing Length Structural Conductor 73' Surface 5342' Intermediate 11895' Production Liner 1620' feet feet feet feet Size Plugs (measured) Junk (measured) Cemented 20" 9-5/8" 7" 260 sx Arctiset (est) 2924 sx PF 'E', 385 sx Class 'G' 200 sx Class 'G' 4-1/2" 205 sx Class 'G' MD TVD 110' 110' 5377' 2198 11928' 9398' 13372' 10633' Perforation depth: measured true vertical 13130'-13190'; 13080'-13104'; 12770'-12828' 10002'-10057'; 10296'-10319'; 10344'-10402' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 @ 11586' Packers and SSSV (type and measured depth) H ES TNT packer @ 11557' HES HXO SSSV @ 2208' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl RECEIVED ~la~ka 0ii & Gas Cons. Commission Anchorage Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: I-~ Copies of Logs and Surveys run [] Oil [] Gas I~ Suspended [] Daily Report of Well Op~t)ons 17. I hereby ce_.~ify.t~attt, he fo/e.a'oing is tr~,~? correct to the best of my knowledge Signed ~/-~.,r~,,,~¢,/~// -~/~_ r , MICHA'ELWlLLIAMS ~--"'~7~%/~ Title Technical Assistant IV Prepared By Name/Number; Service Water & Gas Injector Submit In Duplicate~ Form 10-404 Rev. 06/15/88 - ' B1-16 DESCRIPTION OF WORK COMPLETED Initial Perforation O8/O9/98 SUMMARY The following initial interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 13130'- 13150' MD 13150'- 13170' MD 13170'- 13190' MD ADDPERF 09/15/98 SUMMARY The following additional interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 13154' - 13174' MD STATE OF: ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL .Type of Request: l--lAbandon [] Suspend [~ Plugging [] Time Extension [] Perforate ~, Alter Casing [] Repair Well [] Pull Tubing I-[Variance I~1 Other [] Change Approved Program [] Operation Shutdown I-] Re-Enter Suspended Well ~ Stlrnulste FRAO Programme 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 107' WEL, SEC. 8, TgN, R20E, UM At top of productive Interval N/A At effective depth 5271' NSL, 4149' WEL, SEC. 34, T10N, R4E At total depth 27' .N. aL, 1325' WEL~SEC. 32, TloN, R20E..~ UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Type of well: [] Development [] Exploratory [] Stratlgraphic r'Z~ Service RECEIVED SE? 15 1998 Alaska 0il & 6as Cons. Commission · ' ' 13372' feet Plugs(measured) 10633' feet 13286' feet Junk(measured) 10549' feet Length Size Cemented 73' 20" 260 sx Arctiset (est) 5342' 9-5/8" 2924 sx PF 'E', 385 sx Class 'G' 11895' 7" 200 sx Class 'G' 1620' 4-1/2" 205 sx Class 'G' 6. Datum Elevation (DF or KB) KB = 54.3' -7~ Ur~it or Pi~'Pe~y Name Badarni $. Well Number B1-16 '4. Permit Nuttier ' ~ 9'Z'- 0'80 10. APl Number 50-029-22880 11. Field and Pool Badami Field/Badami Oil Pool MD 'I'VD 110' 110' 5377' 2198 11928' 9398' 13372' 10633' Perforation depth: measured true vertical 13130'-13190'; 13080'-~'P413'; 12770'-12828' 10002'- 10057 '; 10296'-10319'; 10344'-10402' Tubing (size, grade, end measured depth) 4d/2" 12,6# L-80 @ 11586' Packers and 888V (type and measured depth) HES TNT packer @ 11557' HES HXO SSSV @ 2208' 3. Attachments {~ Description summary of proposal 4. Estimated date for commencing operation September 1998 16. If proposal was verbally approved Name of apprpver Contact Engln~er NamelNu/nber; D,ate.approved Detailed operations program [~ BOP sketch Status of well classifications as: ~_] Oil l-"] Gas [_~ Suspended Service Water & Gas Injector Pml~e~ed By Narne/Nurnbe~: Michao! Williams, 554-4657 17. I hereby c~~and c~rrect to the best of my knowledge Signed ~ILL~--'~I~~~L, BREDAFI ' ~ ~'-' ~ Title Subsurface Manager, Badami Commission Use Only Conditions of Approval: Notify Commission so representative m~y witness ,,,vect CoPY Plug integrity ~"r ~ et~,r~ed,,, --- Mechanical Integrity Test ~'~of th~ Oommission Form 10-403 Rev. 06/15t88 BOP Test . Location clearance ~ S~bsequent form required 10-/¥O'7'_~/' Z~O~ Original Signed By David W..l hnstcn C.ommis~ioner Subm~[t In Tffplicate ~T 'fi '~T'~q Memerandum To: P. Collins/J, Powers/M.Goodwin Date: Sop 14, 1998 From: P.Collins AND PE Subject: BADAMI B1-16 Frac Programme B1-16 was completed with a 4 1/2" cemented liner and 4 l/a,, tubing. Frac equipment will be barged from West Dock to Badami, Seawater will be drawn from the Badami dock and heated by a hot oil truck, The CTU will be barged out after this and B1-14 fracs are done if cleanouts are necessary. PTS frac separator is on location ready for flowback. 1. Reperforate 13154- 13174 ft md bkb with big hole charges 2, Pump a 300 bbl data frac, 3. Redesign and pump the frac, Initial calculations give 150,000 lbs 16/20 proppant. 4. Conduct s~ CTU cleanout if necessary. 5. Flow the well back through the PTS flowback separator to clean up proppant. The Deviation across the perforated interval is 14°, at an azimuth of 340°. Attachments to this program include: · Well completion diagram. · Detailed data frac and propped frac program, · Tubing Movement Calculations for Well B1-16. PC L Purdom / R. Warner WSA Team Leader Wellfile Badami B1-16 Frac proceedure Attention: Bob Thayer /Wes Wilder DO NO'I- EXCEED 8,400 surface pressure. Pre - Fr~c Treatment 1. Reperforate 13154 - 13174 ft md bkb . Shoot the guns on balance. Perforation should be with 2 aA" guns, 6 spt 60 degree phasing, big hole charges. Pressure test annulus to 5.000 psi. Equipment will be brought out by barge from West Dock. Berm in and rig up equipment. Seawater will be taken from the Ba, dami dock by vac truck. The water should be pumped into DS tiger tanks via a 3 mm filter and heated by hot oiler to 100 degrees F. Objective: To create a frac of 250 feet X~in the Badami A5 and J2 sands. Pump injectivity test and datafrac followed by the main fracture treatment. 1) Rig up and stab tree saver, (4" Cameron tree, 4 ~/~" L-80 tubing). The surface pressure is estimated to be 5,000 psi for pad. Azimuth = 340° Deviation = 14° Pressure test surface lines to 10,000 psi. Expected treating pressure is between 5,000 and 8,000 psi. Observe trip-out of each pump. After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 8,400 psi. Perform injectivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. With gel at the peris, bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50# linear gel followed by seawater. Over displace ali crosslinked fluid into the parrs by 5 bbls, Shut down and monitor the surface pressure for ~t least 15 minutes, if the near wellbore friction is > 1,000 psi pump a large fluid slug - 50 bbls and flush_ Monitor the decline, if near welibore friction still high, repeat the procedure, Look at both the value and the rate of change of the near wellbore friction. If, required a proppant slug will then be pumped. Once near wellbore friction is ~ 500 psi proceed to Datafrac. 4) Perform 300 bbl Data frac with crosslinked fluid: Pump data frac down to perforations at 5 bpm. With gel at the parrs, bring up rate as quickly as possible to 20 bpm. Over displace data frac by 5 bbls. Displace the data frac with 30 bbl 50 # linear gel followed by seawater. Stop pumping and monitor the pressure decline, Transmit the data to Anchorage for interpretation. Discuss closures and leakoff with town, Redesign the TSO. Pump 150,000 lbs fracture treatment at 20 bpm per modified rsmp. 7) Freeze protect the tubing with 30 bbls diesel Table 1 Volume to Top Perfs Volumes 195 bbls Under Flush 5.0 bbls Flush 190 bbls Post - Frac Treatment 1. Determine proppant top with slickline if necessary. 2. If a clean out is necessary, it will be done once B1-16 and 14 are fracced and the frac equipment out of the way. A CTU will be barged from West Dock. Clean out Carbolite per established procedure, An additional programme will be prepared if the operation is necessary. 3. A PTS fiowback separator is on location, Flow the well through the separator initially to clean up proppant. Tubing Movement Calculations for Well B'[-16 Anchored La0 '[ubing 2 Strings Var 3.2d ~isio~" & Plug Effe. c! B"~llooninq E~iect Pressure Acr~3ss Packer~lement: ~t~l L~nth Chan~e~ -L_pr = -98.53 inches -L_bal ~ 19.04 inches 'P = -5238 psia (up) O inches -F~r = -76718 lbs - F_ba] = -14822 lbs 0.0 feet P~es~ure Buc~lin~ Te~per~u.re Effect F'~p = -89663"[~'(up) t~'bin9 -> packer rome L hb = 0.00 inches ~tmp = -35.66 inches F~c = -185217 lbs (up} PaCker.-~ casing force n = 0 feet F tip = 27768 lbs L ~inimum Design Fa~o[: 1.48 VME String 1 Input, ail strings (Go Io bottom for Instructions Options: ("X" to se[act) 9O 8400 5000 5O 5000 0 3.875 0 String i [- ~000 2000 3.958 4.5 g0000! 12.6} 6.184~ 1 2.8~ 7.21 7.2 7.21 95 50 0 0 mi FinaL Surfnce Temp. (° Fi Final Applied Tubing Pressure /ps0 Final Applied Annular Pressure (psi) Initial Surface Temperature (°F) initial AppEed Tbg. Pressure !psi) Initial Applied Ann. Pressure (psi) Packer seal bore diameter (in) Siackoff (Ibsi -Compress,, +Tension Strin9 2 11 560. 8910 3.958 4.5 80000 12.6 6.184 12.1 8.71 8.6 8.7 110 184 0 0 i'X Igno'~e Pipe=T(;'lerance for VME calcs~.eave Blank ,o Us-e APl T°le,anceii Anchored Tubing (Leave Blanlc for Floating/Pinned tubing)I 1 3Cr Th9 {Leave Blank for La0. Use Tubing option to define other tubing]~ Tubing~ltype} EI3E;7~ 5~- 7E-61 ~~ Sour Se~ice lLeave Blank for Sweet Service)~ Mechanical set Completion {~ave 61ank for Hydraulic Set~ Plug in Tailpipe P below wlug~ ' [psia kr Set~ Pinned at lbs (L~ave blank for Free M°vement~ Design Factors at Top and Bottom of AnchoTed Tubing. 1.67 Tens 2.48 Burst NIA Cotlap 1.48 VME 1,95 Tens 2.12 Burst N/A Col/ap 1.61 VME Tens 13urst Collop VME Top 1 2,12 N/A 1.61 4.76 1.6~ 1.73 Each String ' Floatir~g 2 .MD bottom fit) TVD bottom fit) Tens 'rbg I.D. (in) Burst Tbg O.D. (in) Collop Tbg Yield (psi) VME Tbg Weight (lbs/ltl Tens Casing I.D. [in} Burst Final Ihs/gal tbg ,Collop Initial lbs/gal tbg ~VME Final lbs/gal ann Tens Init/al lbs/gal ann Burst Final bet Ter~p [°F] Collop Initial b0t Temp (°F] VME -P friction {psil~tt) Dogleg (°fi00 ft) Tens 3.46 Burst 2.48 Collap N/A VME 2.33 Tens 4.97 Burst 2.12 Collop NrA VME 2.24 Comp Burst Collop VME Bottom Top '-ubin,",,' Tens 4.97 9urst 2.12 i Collop N/A VME 2.24 Comp 9.89 Burst 1.61 Cotlap NIA VME I ,49 Comp Burst Co/rap VME BoSom Denotes Design Factors Be[ow BP's Suggested Minimum B'PX Sugg gn minimums LLOad capaCity ~_en~,i,~)n..... 1.50....... Load capacity Collaps~" 1,10..... VME (swe~t servibel 1.25i ~ad capacity compression 1.2o Load capacity Burst 1.30 VME (sour se~ice) .m~ '331 '::Lo "~.) For Anchored tubing, weak mink is top of tubing or Anchor Seal: keep Tension and VME fsctors above minimum ':2~ ~'.) For Floating seal assembly over slips[ick: Keep Total negative Len~ Change < < Slipstick Length (=~} Fo~ Pinne6 seal assembly over slipstick, pins will shear and tubing ~ill move it: I F_~ [ > Pin Strength i Kelly bushing to weJlnead (It) Wellhea~t to aea, level ~ .-Bo NSCT Produmlton Tubing HE$ "X' Safely Vatve L~,ndin CAsing HES 'TNT' Pen"n~nanl P~cker HES 'XN" Landing Nipple Wlrallne Enlnj Guide ?' X 41/2' Liner Hanger / Pecker [ni'erme~tala Caslrtg 6apl; 2~"; Random; 60~ph 6Spf; 2~"; Random; 60*ph 6sp(; 2~'; R~ndom; 60~h !PBTD Pro(;lu ellen Caalng I~ale Rev Dy' Commen[s 4/13/96 B.Tumbull Inlllai(3eslgn 7/22/98 P,Colllns As bUltL MD b~sed on plpa 7/2@198 5.Turnbull Revised TVO ~-~/§6 B.Turnbull PeSt Pelfs ~/lzt/95 B.Tumb~ll Add peris , · -- i i i il .i 2208 2144 5377 4548 11557 6908 11574 8922 11586 8933 t 1752 9075 11928 ~230 12770-12828 10002,10o~? 13080-13104 ~o2ge.to3~9 13130-131 aO lO344-t 0402 13286 10405 13372 10576 II I I II I I I IIII B1 16 Ga_LZB_I 13 N~1~.6_,TaZ S_l M21~2_LZ~_l .~Oi V/Y -o. 30~ -0.3, 2,5 ii III I I BP EXPLORATION, Alaska Date: 08-31-98 Trans# 89478 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type Rec Type Rec Date Comments B1-15L1 MAC OH 14-Jul-98 MULTIPOLE ARRAYACOUSTILOG B1-14 SBL CH 04-Aug-98 GAMMA RAY LOG/CCL B1-14 PFC CH 11-Aug-98 GAMMA RAY LOG/CCL B1-14 PFC CH 19-Aug-98 GAMMA RAY LOG/CCL B1-16 PFC CH 09-Aug-98 GAMMA RAY LOG/CCL B1-16 SBL CH 05-Aug-98 SEGMENTED BOND TOOL GR/CCL B1-16 STATIC CH 16-Aug-98 PRODUCTION LOGGING SERVICES/STATIC PRESSURE B1-21 PFC CH 06-Aug-98l GAMMA RAY / CCL B1-21 PFC CH 16-Aug-981 GAMMA RAY / CCL ~'&' 080 Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disldl blueline/1 sepia PETROFINA- I disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP -- 1 blueline BP---1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley · Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: Trans# 07-28-98 89263 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log TypelRec TypelRec Date IComments '~'~'~ ~© B1-16 MAC IOH 15-Jun-O81MULTIPOLE ARRAY ACOUSTILOG Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA /,' AOGCC- I disk/1 blueline/1 sepia PETROFINA- I disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP-- 1 blueline BP ---1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 JUL, 24,'998 " iPM ¢ STATE OF ALASKA ...... . .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ,, EEF,..oo*-- F-l,.**w, 2. Name of Operator BP l]xploratlon (Alaska) Inc. 3. Address P.O.Box 196612, Anchorage, AIc~ka 99516-6612 ~. Locotionofwe/) at surfa<~:e " 3855' NSL 107' WEb SEC 8, T9N. R2OE, UM At top of productive fnterva) At effective depth Af fatal depth 27' NSL 132.~' WEb SEC 32, ]"]ON, R20E, UM 5. Type of well: [~Development L-"lExplorot~ry r--I$ffcrfl¢raphlc [S'ervlce NO. 3975 ?, i5/24 ['~r 6, Datum Devotion (DF or KB) 7, Unit or Property Name BADAMI 8. Well Number BI-1& ~, PbrmltNumber i O. APl Number 50-029-22~80 1. Field and Pool Badaml Fleld/ Badami OI1 Peel 12, Present well condition summary Total depth: measured 13372 feet true vertica 10633 feet Effective depth: measured 13286 feet true vertical 10549 feet Casing Length Structure; Conductor 73' 2D' Surface 534~' 9-5/8" ~ntarmedlofe 11895' Producffon Liner 1620' 4 1/2" Plugs (measured) Junk Cme~ured) Cemented MD fVD 260 ~, Araflset (est) ) 10' 110' 2?24 sx PF 'E', 385 sx ~ 'G' 5377' 2198' 2~ ~ Ola~ 'G' 11928' 9398' 20~ sx Clo~ 'G' 13372' 10633' Perforation depth: measured flue vertical Tubing (size. grade, and measured depth) Packe~ and SSSV (type crud measured aepth) ORIGINAL HE$ TNT pecker at ~ 1 ~7'MD HDS HXO SSSV landing nipple ¢ 2~ ~' ' 3, Attachments [~lDes~ptlon summary of proposal I~-[Petailed operations progrc~m 4. Estimated cJa~ f9r c~ommenclng operahon J ~5, Status of wel clas~flu--~lJons as: -to · I ]6, Ifp posal asv rbafiyajcproved ] ~1OII I ! Se~e Name 0¢ ~prover Date approved [ Contact ~¢~ear N~e /Num~e~ Pat Collins 56~43~ F-~BOP si<etch F-lsu~pended Prep¢edByN~me/Numb~. Pat Coffins 564-4363 17, I herebYsigned/¢/_~/~ ce dlfy~fha t th.,;~ fore gp~ g~/~.j~ls true and correct to fha best of my knowledge~/~,O~,/~ ~/'~ Conditions of Approval: Notify Commission so representative may witness BOP Test / Location c/es~'ance Plug Integrity Mechanical Integrity Test SubseqUent form required 10- /"fO --ir Approved by order of the commission Form 10-403 ~ev, 06/15/88 ....... - ~ Robert N. Christenaon Commissioner Date Submit In Triplicate JUL, 2.4, 'gg8 N0,39s5 P, i6/24 lip ~I:Pl. OFIAtlON Memorandum To: S.Benoit Fro m: Sublect: P,Collins AND PE BADAMi B1-16 Perforation Programme Date: July 21, 1998 B1-16 was completed on 6/13/98. The well will be pre-produced for a period of from 3 to 6 months prior to conversion to a WAG injector. B1-16 is completed with a 10M tree which needs to be changed out prior to perforating. The programme calls for perforating A5 amalgamated prior to startup. Post startup, this interval will be tested, and two further intervals added, with a test between each perforating operation. 1. Change out the 10M tree for a 5M tree. 2. Pull the RHC plug. 3. Run a cement bond log over the 4 ~,~" liner under pressure. 4. Perforate 13124 - 13190 ft md bkb 66' A5 amalgamated Perforation should be 500 psi underbalance with the well shut in for the first gun run. 5. After startup, obtain a welltest of the A5 amalgamated interval. 6. Perforate 12770 - 12828 ft md bkb 58' J2 interbedded Perforation should be underbalanced with the well flowing at a low rate, choked back as necessary to prevent tool movement. 7. When the WHT has stabilised, obtain a welltest. 8, Perforate 13080- 13104 ft md bkb 24' F5 interbedded JUL, 24, '998 I'tO, 3995 P, 29/24 Perforation should be underbalanced with the well flowing at a Iow rate, choked back as necessary to prevent tool movement. 9. When the WHT has stabilised, obtain a welltest. Perforation should be with 2 3,~,, guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. The Deviation across the perforated interval is 16°, PBTD is at 13286 ft MD bkb. Attachments to this program include; Well completion diagram Minilog PC cc L Koenn, Atlas Weflfile JUL 2 3998 0il & Gas Cons. JUL, 24, '~998 ~' ~2PM NO, 39v5 ?, '8/24- _1 i B1 16 JUL, 24, '998 !' 22PM £40, 3S'tb P, iS/Z4 Kelly bushing to wellhead (fl) Wellhead 35.3 19.0 Conductor L-aO N$CT Produc~ior~ Tubing HES "X' Safely' Valve Landing Nipple Surface Casing lES 'TNT" Permanenl Packer HES "XN" Landin~ Nipple Wireline Enlty Guide 7" x 4 I/2" Liner Hanger / Packer Inlermedlale Casing Perforaliorl~ PEtTD Producllon Ca~[ng Rev by Commems I~.Tumbu~f P,CollJna Inilial design As buil~ BP EXPLORATION, Alaska Date: Trans# 06-23-98 89241 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name 'Log Type Rec Type Rec Date Comments B1-16 GR DISK 01-Jun-98 CCL/SBT/GR/MARKED LINE GR '1~1-16 GR CH 01-Jun-98 MARKED LINE GAMMA RAY - SEGMENTED BOND TOOL GR/CCL B1-16 IEL OH 07-Jun-98 TRUE VERTICLE DEPTH - HIGH DEFINITION INDUCTION LOG- GAMMA RAY LOG - B1-16 MAC !OH 07-Jun-98 MULTIPOLE ARRAY ACOUSTILOG / GAMMA RAY LOG B1-16 'IEL IOH 07-Jun-98 HIGH DEFINITION INDUCTION LOG GAMMA RAY LOG / SUB SEA VERTI CLE DEPTH B1-16 Z- OH 07-Jun-98 COMPENSATED Z-DENSILOG/COMPENSATED NEUTRON LOG/ DENSILOG GAMMA RAY LOG B1-16 IEL OH 07-Jun-98 HIGH DEFINITION INDUCTION LOG / GAMMA RAY LOG Nadene Reichert Petrotechnical Data Center Please sign and return one copy of this transmittal to: LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP -- I blueline BP ---1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 VAX ~U'/ bB4 STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: ~-~ Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612. Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 107' WEL, SEC. 8, TgN, R20E, UM At top of productive interval N/A At effective depth 76' NSL, 183' EWL, SEC. 4, TgN, R20E, UM At total depth 0' SNL, 1284' WEL, SEC. 5, T9N, R20E, UM (Planned] J5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) Plan KBE -- 54.3' 7, Unit or Property Name Badami Unit 8, Well Number B1-16 9. Permit Number 98 -80 10. APl Number 50-029-22880 11. Field and Pool Badami 12. Present well condition summary Total depth: measured 4839 true vertical 4267 Effective depth: measured 4839 true vertical 4267 feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Length 80' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Size Cemented 20" 260 sx AmticSet (Approx.) MD TVD 116' 116' ORIGINAL Packers and SSSV (type and measured depth) N/A ~ 3. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 13, 1998 16, If proposal was verbally approved Blair Wondzell Name of approver Contac! Engineer Name/Number: Mike Mil/er, 564-$066 5/11/98 Date appr.ov..ed 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water&Gas Injector Prepared By Name/Number: Carol W/they, 5~4-4114 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge Signed Mike £. Miller ''~¢, ~,~__= Title Badarni Drilling Team Leader Commission Use Only Conditions of Approval: Notify Commission so representative may witness J Approval NO' .~ F ~ %/,¢ Plug integrity ~ , BOP Test ~ Location clearance~ Mechanical Integrity Test Subsequent form required lO- ",,'~i'~D~t Signed By Approved.. by order of the Commission _ :orm 10-403 Rev. 06/15/88 -'~.~vid W..J0hn_.~tnn ,~¢,6 O0?''j Commissioner Submit In Triplicate 05114198 12:26 P'AX 907 564 5]93 BP EXPLORATION ~ AOGCC ~003 d rvices rilling Date: May 14, 1998 To: Mr. Blair Wondzell, AOGCC From: Mike Miller, BP Badami Subject: Badami B1-16 Fish and Plug-Back Mr. Wondzell; This letter is to follow-up our verbal conversation of May 11, 1998 regarding the fish in B1-16 and the plug-back and sidetrack. When we spudded the B1-16 well on May 3, 1998, we immediately encountered junk in the hole. A tungsten carbide cutter tooth from the dry hole auger used to drill the 26" conductor hole was jammed between the three cones in the first 12-1/4" bit we ran. The conductors were ail drilled in the conventional style with a dry hole auger in approximately March 1997. Some parts of the auger must have come off, which we encountered with the first bit. We spent the next several days drilling and milling on junk, with no further recovery of junk from the hole. We were then able to drill ahead to a depth of 4839' md (4232' b/d), where the drill string became stuck while drilling. A free-point indicated the assembly was stuck near the bit. Fishing operations failed to free the fish. In fact, during the fishing operation, the hole deteriorated to the extent that the fishing assembly also became stuck (possible destabilization of the wellbore by the jarring action). We were able to back off above the fishing assembly to recover the drill pipe. On May 13~h we set a balanced cement plug on top of the fish (see attached diagram). Our intent today, May 14'h, is to kick off on top of the plug and sidetrack around the fish. There is no change in the bottomhole location target. If additional information if requested, please contact me at 564-5066. 05/14/98 12:27 FAX 907 564 5193 BP EXPLORATION ~ AOGCC ~004 Bl-16 Fish Lost 5/13/98 Top of Cement -3700' MD Top of Fish 4413' MD 3924' TVD 144 bbls of 16.4 ppg Class G Cement Accelerator - 8"" '~'::";"?!?:~"::' 5 - 8" Drill Collars 8" Lubricated Bumper Sub Screw-in Sub Mechanical Jar 8" Short NlvlDC 12-1/4" Hole @ 43 deg 3 - 8"NMDC TD 4839' MD 4232' TVD 8" NMDC "MWD" 8" NM Mandrel Body 8" Short NMDC/12" Mandrel STB 8" - 1.5 deg Motor 12" Stabilizer 12-1/4" STC M05SODCL TONY KNOWLE$, GOVERNOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 24. 1998 Mike E. Miller Badami Drilling Team Leader BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Badami B 1-16 BP Exploration (Alaska), Inc. Permit No. 98-80 Sur. Loc. 3855'NSL. 107'WEL. Sec. 08, T9N. R20E. UM Btmnhole Loc. 0'SNL, 12845VEL, Sec. 05, T9N, R20E, UM Dear Mr. Miller: Encloscd is thc approved application for permit to drill the above rcferenccd well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other rcquired permitting determinations are made. Your request for diverter variance is approved. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling bclow the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chaim~an BY ORDER OF THE COMMISSION dlffEnclosurcs CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK/:, JIL AND GAS CONSERVATION CO,~..!VIISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [~ Drill E] Redrill Ilb. Type of well F"I ExplOratory I-'1Stratigraphic Test [-I Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE - 54.3' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 367011 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3855' NSL, 107' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 187' SNL, 1067' WEL, SEC. 5, T9N, R20E, UM B1-16 At total depth 9. Approximate spud date Amount $200,000.00 0' SNL, 1284' WEL, SEC. 5, T9N, R20E, UM 04/26/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 367006, 0'I B1-15, 5.5' at 500' MD 2533 13294' MD / 10729' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 43° Maximum surface 4400 psig, At total depth ('TVD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 5184' 35' 35' 5219' 4554' 2880 sx PF 'E', 380 sx Class 'G' 8-1/2" 7" 29# USS-95 BTC-Mod 12150' 33' 33' 12183' 9854' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 1261' 12033' 9744' 13294' 10729' 170 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner measured - Perforation depth: I~v true vertica erter Waiver Reques t~0~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refractiog Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ContactEneh~eerName/Number, M,,eMiller.,G4-SOGG~ o~.'~~~----~i~ *ro,~rodByN~mo/Nombor: 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed M~e E. Mi,e~ Title Badami Drilling Team Leader Date Commission Use Only Permit Number APlNumber I ApprovalDate_,., I See cover letter /~.. ~2 50- 4:~..%'~'..-- 2.2.. ~'~'O ,~.~.Z/~.--,~'/-~ for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required []Yes 'l~ No Hydrogen Sulfide Measures []Yes'[~No Directional Survey Required J~Yes D No Required Working Pressure for BOPE []2M; •3M; 1--15M; ,[~10M; D15M ~~ ~-'"'~/~ )/~'Z:)/~'~'i ~'? ') by order of Commissioner the commission Date Approved By Form 10-401 Rev. 12-01-85 Submit In Triplicate B 1-16 Injector PERMIT Shared Services Drilling Contact: Mike Miller 564-5066 I Well Name: I B1-16 I Type of Well (producer or injector): Well Plan Summary I lnject°r I Surface Location: Badami Sand A5 Primary tar~let Bottom Hole Location (TD) 3855' FSL 107' FEL SEC 8, T9N, R20E, UM, AK 187'FNL 1067' FEL SEC 5, T9N, R20E, UM, AK 0' FNL 1284' FEL SEC 5, T9N, R20E, UM AK I AFE Number: I 880456 I I Ri~l: I Nabors 28E Estimated Start Date: IMD: 13294 I April 26, 1998 I Operating days to complete: I Well Desitin' ITVD: 10729' BRT Ultra slimhole IKBE: 54.3 AMSL Formation Markers: Formation Tops MD TVD (bkb) Remarks base permafrost 1989 1984 Base West Sak 10259 8344 Shallowest Badami Sand 11566 9375 Badami Sand K2n 11908 9646 Badami Sand J2 12386 10026 Badami Sand X3 12404 10041 Badami Sand A5 12887 10425 Primary Sand Total Depth 13294 10729 Casin~l/'l'ul~ in~l Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 5184 35/35 5219/4554 8-1/2" 7" 29# USS95 BTC 12150 33/33 12183/9854 mod 6" 4-1/2" 12.6# L-80 BTC 1261' (150' 12033/9744 13294/10729 mod lap into 7") Tubing 4-1/2" 12.6# L-80 NSCT 11840 33/33 11873/9627 Internal yield pressure of the 7" 29#/ft USS95 casing is 9690 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. B 1-16 Injector PERMIT Logging Pro~lram: Open Hole Logs: Surface None Intermediate MWD/GR on last bit trip Production Hole RFT Cased Hole Logs: run 1' HIDL/ZDL/CN/MAC run 2: MRIL run 3: 5" STAR run 4: RFT'S (2 ea fluids, 10 ea. pressures ) MWD/GR/RESlSTIVlTY last bit trip 2 fluid samples, one in F5 and one in the A5. 10 pressure samples · SBT required on intermediate and production casing. Mud Pro~lram: I Special design considerations I None Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.0 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.4 55 15 10 20 9.5 4-5 Well Control (Secondary): Well control equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file. Diverter Waiver requested. Directional' [ KOP: [ 1% 300' MD/I-VD 2® 1614'md/1612' tvd Maximum Hole Angle: [ 43° Close Approach Well: I See Sperry Sun Anti Collision Scan Summary (attached) Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. B 1-16 Injector PERMIT Badami B1-16 Injector Proposed Summary of Operations 1. The 20" conductor and cellar are already installed (all cellars and conductors were installed in winter 1997). Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 28E drilling rig. Install 21-1/4" Hydril MSP annuluar preventer. Note: Diverter waiver does not require the installation of the 16" diverter line. 4. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD. , Run 9-5/8" casing and cement to surface in two stages. Insure a minimum of 2500 sxs of Permafrost "E" cement is available for the 2nd stage displacement. Note: Revised Cement procedure to prevent lost circulation. 7. ND 21-1/4" diverter and NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi minimum. , Pick up BHA. RIH, test casing to 3000 psi. Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST as per SSD Standard Operating Procedure. Contact Badami Team Leader or SSD Superintendent with LOT results before drilling ahead. 9. Drill 8-1/2" hole to intermediate TD with MWD directional surveys. Plan to have MWD/GR picked up on last bit run prior to TD of 8-1/2" intermediate hole section. 10. Run 7" 29# BTC mod USS95 intermediate casing. Cement as per Cement Basis of Design. 11. Test BOPE to 6000 psi. 12. RIH w/6" drilling BHA, clean out cement to float collar, circ annulus 200% & test intermediate 7" 29# BTC mod casing to 5500 psig for 30 min. 13. Drill out float collar, float joints, float shoe. Drill 15-20md below intermediate shoe depth. Treat cement contamination. Change out mud system to 2% KCL LSND. Perform a FIT to 15.5 ppg. 14. Drill to TD as per directional plan with MWD directional tool. Plan to P/U MWD/GR/Resistivity. 15. Run open hole logs and RFT's as per plan. RFT pressure points to be forwarded to Rig Site Team via the SST/DDT. 16. Run and cement 4-1/2" 12.6# L80 production liner with 2-7/8" VAM inner string, displace cement with drilling fluid. Set liner hanger and liner top packer. Release off of 4-1/2" 12.6# L80 BTCmod production liner, pick up and clear top of tieback extension and circulate excess cement/contaminated mud to surface the Iongway. 17. Test 4-1/2" 12.6# BTC mod production liner and 7" 29# BTC mod casing to 3500 psi for 30 minutes to confirm liner and lap pressure integrity. Circulate well to completion fluid (fresh water) with 25gals/100 bbl of 7726 Corexit corrosion inhibitor. Re-test 4-1/2" production liner and 7" intermediate csg. to 5500 psi for 30 minutes. 18. Run SWS cased hole cement evaluation log ( 7" x 4-1/2"). Run CBL with 0 psi gauge pressure and with 1000 psi gauge surface pressure. 19. Run 4-1/2"12.6# L80 NSCT tubing per completion procedure. Set two way check in FMC 4-'1/2" tubing hanger. Note: B1-16 will require a Cameron 11"10M x 4-1/16" 10M tubing head adaptor and 4-1/16" 10M Cameron tree. APR B 1-16 Injector PERMIT 20. ND 13-5/8" 10M Hydril BOPE, NU 11" 10M x 4-1/16" 10M FMC tubing head adapter and 4-1/16" 10M Cameron tree and test tree to 5500 psi. Pull two way check. 21. Freeze protect 4-1/2" x 7 "annulus and 4-1/2" tubing with diesel - U- tube from annulus to tubing via 2-1/16" 10M FMC tubing head isolation valve. Freeze protect 7"x 9-5/8" annulus to 2200' tvd. 22. Drop Halliburton "TNT" packer setting ball/rod assembly - to locate in RHC sub in XN nipple. Set HES TNT permanent packer with 5000 psi. Test 4-1/2" 12.6# L80 NSCT tubing to 5500 psi for 30 minutes. Test 4-1/2" x 7" annulus above packer to 5500 psi for 30 minutes. Set BPV in 4-1/16 10M FMC tubing hanger. 23. Rig down and prep Nabors 28E/location for rig move. DRILLING HAZARDS AND RISKS: Nearest offset wellbore - B 1-16 Injector PERMIT See Sperry Sun Anti-Collision Scan Summary I Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Well Control- Badami sands are overpressured- mud weight of 12.4 ppg will be required to drill to TD. Maintain 6" production hole section circulation rates @ 190 gpm to prevent loss circulation problems while drilling the Badami reservoir. B 1-16 Injector PERMIT Badami B1-16 SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" SPACER: 50 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 380 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 380 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 2500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX NO SACKS: To be determined on job x job basis MIX WATER: 11.63 gal/sk B 1-16 Injector -_~, PERMIT Badami B1-16 INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER- 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 185 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. Badami B1-16 LINER CEMENT PROGRAM- HALLIBURTON CASING SIZE: 4-1/2" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight (adjust weight to ECD if critical) CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .45% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 170 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on open hole gauge annular capacity, plus 50% excess, plus 80' shoe joint, plus liner lap plus 200' above liner top with drillpipe in hole. s mm -sunr Shared Services Drilling I .~,i/~ .,-~,2a~=s ~.~2c s s Welt: B1-16 Wp4 O-- KOP: Stad Dir ~ 1.000'/10~: 300.0~ MD, 300.0~ ~ i Proposal Da~ for BI-t6 Wp4 . 3~.~ ~ ~" v~ ~: w~ ~f~e~ Continue Dir ~ 1.000'/10~: 600.0~ M D, 5~.86fl ~D I ~/~ u~s: ...- ~ ~f~: T~ ~h 7~.~ End Dir, Sail ~ 6.000~: 914.98ff MD, 913.~fl ~ v~ ~n~: M*asumd / 23~.32 3359.80 43.~ 9.~ 31~.12 53~.10N .... ~ .................... B~e P~t - 1984.30 TVD ] 4~.42 43.5~ 358 ~ 4329.~ 1585 og N ~9.11 E 1~.76 Conlinue Dir ~ 2.500'/100ft: 2414.98ft MD, 23~.32ft ~D ,~I:~ I~:~ ~:~ to571.3D 112x 53 W 23~.~ - ~ D2~.92 37.7~5 326 172 I0729.30 6710.21 N H,~.O7 W 3~. o.2a5 24O0 - ~nd ~ir, Sail ~ 43.000~: 335~.8~ MD, 3~07.~2~ ~ 35~.~~... Sla~ Dir ~ 2.000'/10~: 4531.85ff MD, 40~.3~ ~D 47~.~ ~ End Dir, Sail ~ 43.5~': 4~9.4~ MD, 4329.~ff ~D ~ .......-- ~" 9 5/8" Casing - 5219.29 MD, 4554.30 ~D ~4O00m - ~-~~ ~000 - .Top Mid Br~ki~ (T~K) - 6~3.30 8400 -- --Top ~ning - 8~4.30 ~D 0 ~ 200 2400 3~00 4g00 Scale: ~lneh = ~200~ VO~ie~l ~tiO~ Socfion ~imuth: ~40.805~ ~rue Rodh) ~ - ~h~low~t Badmi S~d - 9375.30 ~D ~ 9~00 --__ _ _ ~ - -~n- 9~6.30 ~ [ PROPOSAL TARGET SUMMARY ~ 7" Liner- 12183.23 MD 9854.30 WD ~ ..... j T~ge{ Na~: : O~ ~d~tes: W~ ~ts ~' Total Oeo~ · 132~.9~ MD. 10729.3~ ~ ~~~~ ~~: 0~14/98 6000 7200 ~7 N~ ~ate R~s. ~ Scale: linch = 1200ff Vedical Section Section ~imuth: ~9,893' (Tree Nodh) ~ ~3, USF~ ~t: SP~I~I~'SI-II-II Shared Services Drilling I .~)i.~[IQ o.,~.L,.~- s~.v,cEs Well: B1-16 Wp4 uest Scale: linch = 1000R Eastings -2000 -1000 0 1000 2000 3000 I I I I I I 7000 -- L 7000 otal 132~.~ MD, 10729.3~ ~D Dep~ t~ ~. _ ~arget: ~3094.66ff MD, 10571.30ff ~ Bl-16 Target- Circle ,, ~.~ ~ 10~71.30 ~- 560Z50 ~ 1128 32 W ~ooo - ..... ~.~. ~7" Liner- ~2~83.23 MD, 9854.30 WD - ~ooo 5000 - - 5000 82~.~ 78~.~ I 4000 - 7~.~ ~ - 4000 o 3000 - s~.m - 3000 I 2000 - - 2ooo u ~ uasm~ - 52~.2~ MD, 4554.30 ~D ~.~ ~ .... find Dir, Sail ~ 43.530*: 4~0~.4~ MD, 432~.~ ~D aa~.~ ] .... 8ta~ Bit ~ 2.000°1~0~: 453~.85fl M~, 40~.3~ ~ 1 3~.~~. ~000 -- -- ~000 ~.ffi 32~ ~ . [nd Dk, S~il ~ 43.000~: 335~.8~ MD, 3~7A2~ ~D ~11 2~.~/~--- C ~11 KOP: S[a, Dir ~ 1.~0"/10~: 300.0~ MD 300.0~ ~D .. On,hue Dir ~ 2.500"/10~: 2414.98ff MD, 2396.32ff ~D ~ 0 - ContinueDir~l.000'/10~:~0.0~M~ 5~.86~D .i;:::J .-Sta~Dir~2.500'/10~:1614.9~MD, 1612.47~D -- 0 · ~ [n~ ~r, Bail ~ ~.0~': ~4.S~ MO~ 0~ 3.~ ~ --- ::: ~ ¢ :- find ~r, ~ail ~ 0.000*: ~ 5~.0~ MD, ~ 5~2.47~ ~ .- I I I I I I -2000 -1000 0 ~ 1000 2000 3000 Scale: linch = 1000E Eastings Reference is True No~h PROPOSAL TARGET SUmmARY J SURFACE LOCATION J PLOT DATE: 04/14/98 .... ~ ............. ~j// ~ 3. USF ~: r ~* ~ DRILLING c~EER V I r"IES 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Drilling Mike Cook Approved Well Close Approach Review B1-16 Wp4 Mike, The above mentioned well has been scanned using standard anti-collision methods via DEAP. The scan was performed with the following parameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (per 1000') 13,384.25 ' 200.00' 100.00 ' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 100' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50 ' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 100' at the Start Scan Inspection Zone as stated above. These numbers are used to produce a f'mal scan radius of 1538.425' which is 769.2125' larger than DEAP's default value of 769.2125' At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation from Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Planned Well Relative Allowable Shut-in Required? (Seperation notes) Comparison Subieet Well Status Well: Depth Seperation Azimuth Deviation as Tested ('= Existin~ Surve~) F= IVelI Plan MD) (Point to Point) (TC Directlon) (Approx~ TL Dist) B1-01 801.82'MD · 145.44' 270.90 ° 139.09 ' No Well is not on-line yet Minor BI -11PBI 1100.68 'MD 49.18 ' 251.60 o 41.90 ' No Well is not on-line yet Minor WDF:BI-14Wp7 400.16 'MD 19.43 ' 274.60 o 15.94 ' No Well is not on-line yet Minor Bl-14temp-prox 400.16 'MD 20.44 ' 274.50 ° 16.54 ' No Well is not on-line yet Minor Bl-14ternp-prox 2629.18 'MD 89.53 ' 290.90 o 71.37 ' No Well is not on-line yet Minor B 1-18temp-prox 399.72 'MD 21.49' 77.70 ° 17.57 ' No Well is not on-line yet Minor BI-I 8temp-prox 1698.66 WID 21.20' 108.40 ° 9.41 ' No Well is not on-line yet Minor B1-21 499.03 'MD 47.51 ' 85.10 o 42.89 ' No Well is not on-line yet Minor BI-21 598.75 'MD 47.89' 86.10 ° 42.89 ' No Well is not on-line yet Minor THE FOLLOWING WELL IS NOT DRILLED YET, THOUGH DEVIATION FROM THIS WELL WILL EFFECT IT'S DRILLING. WDF:BI-15Wpl0 499.91 'MD 9.59 ' 291.00 o 5.50 ' No Well is not on-line yet WDF:BI-15WpI0 2108.46 'MD 29.06 ' 311.20 ° 13.77 ' No Well is not on-line yet Minor Minor Tolerance Plot required: YES Close Approach Comments: The B1-14 and B1-18 temp-prox files in DEAP are the actual surveys taken at the rig.., this is due to the definitive not being published at the time of the scan. Close Approach Scan Performed by: Checked by: Approved by: B1-16 Wp4.xls- AWD Proximity Review 4/15/98 The Surface hole (o. zo0o) close approaches are as follows B1-01: 139.09' allowable deviation at 801.82' MD. (Shut-in Condition) WDF:BI-14Wp7: 15.94' allowable deviation at 400.16' MD. (Shut-in Condition) Bl-14temp-prox: 16.54' allowable deviation at 400.16' MD. (Shut-in Condition) WDF:BI-15Wpl0: 5.5' allowable deviation at 499.91' MD. (Shut-in Condition) Bl-18temp-prox: 17.57' allowable deviation at 399.72' MD. (Shut-in Condition) Bl-18temp-prox: 9.41' allowable deviation at 16~38.66' MD. (Shut-in Condition) B1-21: 42.89' allowable deviation at 499.03' MD. (Shut-in Condition) B 1-21: 42.89' allowable deviation at 598.75' MD. (Shut-in Condition) The Deep hole (2000- TD) close approaches are as follows WDF:BI-15Wpl0: 13.77' allowable deviation at 2108.46' MD. (Shut-in Condition) B1-16 Wp4.xls- AWD Proximity Review 4/1 §198 H 13438~; I DATE CHECK NO. 02/18/.g8 100134386 VENDOR ALASKAST 14 OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 021798 CK021798I 100. O0 100. O0 HANDLINQ INST' s/h kath§ campoanoe x 5122 HE ATTACHED CHECK IS IN PAYMENT FOR ri'EMS DESCRIBED ABOVE. ~110]1~1'-~1~ ~ 4 .~,~. ;~,.~-t -~ ~-~-~ ~-~.-"~ · WELL PERMIT CHECKLIST COMPANY FIELD & POOl.._ .......... .~p/0 ~ INI'[ CLASS ADMINISTRATION ,¢,~2 [')A'I [' · WELL NAME 1 I'¢Ililil h"~.' attaclled N 2 I ease ~lunlber ap[nopJ~ale N 3 Unique well name and nurnbel N 4 Well Iocaled m a defined pool ........ N 5 Well Iocaled proper dislance from dlilling unil boundary 6 Well located proper dislance from other wells . . 7 Sufficient acreage available in drilling unit 8 If devialed, is wellbore plat included 10 Operator has app~opriale bond m force 1 1 I:'ernut call be issued will,out conservatior] ordel 12 ['ernul can be issued without administrative approval 1'/ (:~ lmlnul be approved before 15-day wait GEOL AREA PROGRAM: exp [] dev [] redrll[] serv[]wellboreseg I ann disposal parareq .~;::~.'~,~ UNIT# ~'_ O~.~.,~ ON/OFF SHORE __~?_.__~.~ REMARKS ENGINEERING APPR DA],E GEOLOGY 14 15 17 18 19 20 21 22 23 24 25 26 27 28 29 Conductor string provided . . Surface casing protects all known USDWs . . CMT vol adequale Io circulate on conductor & surf csg. CMI vol adequate to tie-in long string to surf csg CMl will cove~ all known produclive horizons.. Casing designs adequate for C, 'f, B &permatrost Aclecl~ate tankage or' reserve pit ......... 30. Pernut can be issued w/o hydr'ogen sulfide measures 31 Data presenled on polential overpressure zones 32. Se~s~nic analysis of shallow gas zones. 33 Seat)ed condition survey (if off.-shole) . . 34 Cnr'd;'ml ~lan~elpl~olm for we_eklyprogress re[)qris lexplorato~/ only] Il a re-dl'ill, has a 10-403 for abandonment t)een approved. ---Y---N-~_~ ................... _._"_ .......................................................................................................................... Adeqt,atewellboreseparationproposed . . ~ ~~_~ ~~ If diver'ter required, does il meel regulations ..... ' [)rillinfl fluid program schematic: & eqtlip list adeqLlale ~N ~ B()i.'[:::r,. do II~ey meet regulatio~ BOPE p~ess rating appropriate; test Io sis Choke mar, ifold complies w/APl PR-53 ~4~. [ ~... ~N Z Work will occur without operation shutdown ~¢~ Is p~ese~me of tI:,S gas probable. Y~ V i O E _(._.).~. Y ENGINEERING' W '" COMMISSION DWJ_.~. RNC co Comments/Instructions' /. Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Oct 02 12:09:11 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 10 AK-VC-80215 S. NEUBAUER D. MASKELL OPEN HOLE R ¢EiVED OCT 08 1998 ~aC-,,a Oil & ~as Oo,~. Comm_i.~br~ Bl-16 500292288000 ~~ ~ EXPLO~T~ON (~S~), ~N~. SPERRY-SUN DRILLING SERVICES 02-OCT-98 MWD RUN 12 AK-VC-80215 A.WEAVER N.SCALES 8 09N 020 3855 107 54.30 52.80 19.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12.250 9.625 5377.0 3RD STRING 8.250 7.000 11928.0 PRODUCTION STRING 6.000 13372.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 TO 7 REPRESENT WELL Bl-16 PB1. THESE ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 8 AND 9 ARE WELL Bl-16, DIRECTIONAL ONLY, AND NOT PRESENTED. 4. MWD RUN 10 IS DIRECTIONAL WITH NATURAL GAMMA RAY (NGP) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUN 11 DID NOT DRILL OUT OF THE CASING SHOE AND IS NOT PRESENTED. 6. MWD RUN 12 IS DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 7. A CHANGE FROM SCINTILLATION DETECTOR (NGP) TO GEIGER-MUELLER TUBE DETECTORS (DGR) OCCURS AT 11876'MD, 9238'TVD. 8. DEPTH SHIFTING/CORRECTION OF THE MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR DAVE GOODWIN OF BP EXPLORATION (ALASKA), INC. ON 10/01/98. LDWG DEPTH SHIFTING TO ANY OTHER LOG IS WAIVED AS PER DAVE GOODWIN ON 10/01/98. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13372'MD, 10633'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 5323.5 ROP 5351.0 RPD 11900.0 RPM 11900.0 STOP DEPTH 13325.0 13373.0 13332.0 13332.0 RPS 11900.0 RPX 11900.0 FET 11939.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 13332.0 13332.0 13332.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 10 5390.0 11944.0 12 11944.0 13372.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5323.5 13373 9348.25 16100 ROP 6.9239 1023.05 126.918 16045 GR 13.262 118.767 67.0918 16004 RPX 0.2442 106.228 8.33984 2865 RPS 0.3022 2000 9.9007 2865 RPM 0.2713 2000 47.1789 2865 RPD 0.1948 2000 34.7296 2865 FET 0.9656 5.6231 1.63606 2786 First Reading 5323.5 5351 5323.5 11900 11900 11900 11900 11939.5 Last Reading 13373 13373 13325 13332 13332 13332 13332 13332 First Reading For Entire File .......... 5323.5 Last Reading For Entire File ........... 13373 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5323.5 ROP 5351.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11875.5 11944.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUPJkL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 27-MAY-98 ISC 5.06 NGP 5.74 MEMORY 11944.2 5390.0 11944.2 28.2 49.7 TOOL NUMBER NGP SPC 217 8.500 8.5 BENT./PAC, R GEL 10.00 53.0 10.6 900 11.4 .000 .000 .000 58.9 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 10 FT/H 4 1 68 4 2 GR MWD 10 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5323.5 11944 8633.75 13242 5323.5 ROP 6.924 1023.05 143.99 13187 5351 GR 13.262 107.059 61.7782 13105 5323.5 Last Reading 11944 11944 11875.5 First Reading For Entire File .......... 5323.5 Last Reading For Entire File ........... 11944 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11876.0 13325.0 RPD 11900.0 13332.0 RPM 11900.0 13332.0 RPS 11900.0 13332.0 RPX 11900.0 13332.0 FET 11939.5 13332.0 ROP 11944.5 13373.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 06-JUN-98 ISC 5.06 NGP 5.74 MEMORY 13372.0 11944.0 13372.0 14.0 27.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0994SP4 P0994SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL POLYMER 12.10 52.0 11.9 4200 6.3 .600 .271 .380 .950 77.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 12 FT/H 4 1 GR MWD 12 API 4 1 RPX MWD 12 OHMM 4 1 RPS MWD 12 OHMM 4 1 RPM MWD 12 OHMM 4 1 RPD MWD 12 OHMM 4 1 FET MWD 12 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 11876 13373 12624.5 ROP 10.0692 373.359 48.1431 GR 34.9132 118.767 91.1122 RPX 0.2442 106.228 8.33984 RPS 0.3022 2000 9.9007 RPM 0.2713 2000 47.1789 RPD 0.1948 2000 34.7296 FET 0.9656 5.6231 1.63606 First Last Nsam Reading Reading 2995 11876 13373 2858 11944.5 13373 2899 11876 13325 2865 11900 13332 2865 11900 13332 2865 11900 13332 2865 11900 13332 2786 11939.5 13332 First Reading For Entire File .......... 11876 Last Reading For Entire File ........... 13373 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Scientific Technical Services Service name ............. LISTPE Date ..................... 98/10/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
